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Table 18: Non group settings

Parameter

Values (Range)

Unit

Step

Default

Description

Protocol Security

Mode

1=App. authentica-

tion
2=TLS and appl.

auth.
0=Off

0=Off

Protocol Security

Mode - 0: Off; 1:

Aplication authenti-

cation; 2: TLS and

Aplication authenti-

cation

Reply timeout

100...120000

ms

1

2000

Reply timeout

Exp Sesn key Chg

Intv

0...14400

s

1

1800

Expected Session

key change interval

- Value zero will in-

dicate that interval

is not used

Exp Sesn key Chg

Cnt

2...10000000

1

4000

Expected session

key change count

Max Sesn key Stat

Cnt

1...255

1

5

Maximum session

key status count

Sec Stat Cnt Grp

1=Group 1
2=Group 2
3=Group 3
4=Group 4

4=Group 4

Secure statistics

counter group

Sec Stat Cnt IOA

1...65535

1

61000

Information object

address for secure

statistics counters

3.1.13

IEC 101-104 Secure statistics thresholds settings

Table 19: Non group settings

Parameter

Values (Range)

Unit

Step

Default

Description

Unexpected Msgs

1...65535

1

3

Security statistics

threshold for unex-

pected messages

Auth failures

1...65535

1

5

Security statistics

threshold for au-

thorization failures

Authn failures

1...65535

1

5

Security statistics

threshold for au-

thentication fail-

ures

Reply timeouts

1...65535

1

3

Security statistics

threshold for reply

timeouts

Rekeys Authn fail-

ure

1...65535

1

3

Security statistics

threshold for re-

keys due to authen-

tication failure

Total Msgs Tx

1...65535

1

100

Security statistics

threshold for total

messages sent

Total Msgs Rx

1...65535

1

100

Security statistics

threshold for total

messages received

Total Crit Msgs Rx

1...65535

1

100

Security statistics

threshold for total

critical messages

received

Discarded Msgs

1...65535

1

10

Security statistics

threshold discar-

ded messages

Table continues on the next page

1MRS759142 F

Basic functions

REX640

Technical Manual

65

Summary of Contents for RELION REX640

Page 1: ... RELION PROTECTION AND CONTROL REX640 Technical Manual ...

Page 2: ......

Page 3: ...Document ID 1MRS759142 Issued 2023 02 07 Revision F Copyright 2023 ABB All rights reserved ...

Page 4: ...ed or disclosed only in accordance with the terms of such license Trademarks ABB and Relion are registered trademarks of the ABB Group All other brand or product names mentioned in this document may be trademarks or registered trademarks of their respective holders Open Source Software This product contains open source software For license information refer to product documentation at www abb com ...

Page 5: ...ace which should be connected to a secure network It is the sole responsibility of the person or entity responsible for network administration to ensure a secure connection to the network and to take the necessary measures such as but not limited to installation of firewalls application of authentication measures encryption of data installation of antivirus programs etc to protect the product and ...

Page 6: ...cal equipment for use within specified voltage limits Low voltage directive 2014 35 EU This conformity is the result of tests conducted by the third party testing laboratory Intertek 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 internat...

Page 7: ...are 42 2 3 Local HMI 45 2 4 Switchgear HMI 49 2 4 1 Bay overview area 51 2 4 2 Physical and virtual Home buttons 52 2 4 3 Navigation 52 2 5 Physical ports 53 2 6 Web HMI 53 2 7 User authorization 55 2 7 1 Local user account management 55 2 7 2 Central account management 55 2 8 Station communication 56 2 9 Modification Sales 56 3 Basic functions 57 3 1 General parameters 57 3 1 1 Authorization sett...

Page 8: ...78 3 2 Communication 79 3 2 1 Ethernet addresses for HMI 80 3 2 2 Self healing Ethernet ring 80 3 2 3 Ethernet redundancy 80 3 2 4 Process bus 83 3 2 5 Secure communication 85 3 2 6 Communication services control 85 3 2 7 Serial port supervision SERLCCH 89 3 2 8 Serial port supervision SERLCCH 90 3 2 9 Assigning of a serial communication protocol to a COM serial port 90 3 2 10 Physical locations o...

Page 9: ...evel L R 136 3 8 5 Station authority level L R L R 138 3 8 6 Station authority level L S R 139 3 8 7 Station authority level L S S R L S L S R 140 3 8 8 Control mode 141 3 8 9 Signals 141 3 8 10 Settings 142 3 8 11 Monitored data 143 3 9 Fault recorder FLTRFRC ANSI FR 143 3 9 1 Function block 144 3 9 2 Functionality 144 3 9 3 Analog channel configuration 145 3 9 4 Signals 146 3 9 5 Settings 146 3 ...

Page 10: ...V_MV 208 3 18 4 Received GOOSE 8 bit integer value information GOOSERCV_INT8 209 3 18 5 Received GOOSE 32 bit integer value information GOOSERCV_INT32 210 3 18 6 Received GOOSE interlocking information GOOSERCV_INTL 211 3 18 7 Received GOOSE measured value phasor information GOOSERCV_CMV 212 3 18 8 Received GOOSE enumerator value information GOOSERCV_ENUM 213 3 19 Type conversion function blocks 2...

Page 11: ...SPCGAPC ANSI SPCG 259 3 20 14 Pulse counter for energy measurement PCGAPC 265 3 20 15 Hotline tag HLTGAPC 271 3 20 16 Voltage switch VMSWI ANSI VSWI 274 3 20 17 Current switch CMSWI 278 3 20 18 Generic up down counter UDFCNT 281 3 20 19 Current sum CMSUM ANSI CSUM 283 3 20 20 Transformer data combiner OLGAPC 285 3 20 21 Controllable gate 8 channels GATEGAPC 287 3 21 Standard logic operators 289 3 ...

Page 12: ...channel supervision RCHLCCH 315 3 25 2 Ethernet channel supervision SCHLCCH 317 3 26 External HMI wake up EIHMI 320 3 26 1 Function block 320 3 26 2 Functionality 320 3 26 3 Operation principle 320 3 26 4 Application 321 3 26 5 Signals 322 3 26 6 Settings 322 3 26 7 Monitored data 322 3 27 HMI Ethernet channel supervision HMILCCH 323 3 27 1 Function block 323 3 27 2 Functionality 323 3 27 3 Signal...

Page 13: ...EFPADM ANSI 21NY 490 4 2 5 Rotor earth fault protection injection method MREFPTOC ANSI 64R 515 4 2 6 Harmonics based earth fault protection HAEFPTOC ANSI 51NH 521 4 2 7 Wattmetric based earth fault protection WPWDE ANSI 32N 529 4 2 8 Third harmonic based stator earth fault protection H3EFPSEF ANSI 64TN 541 4 2 9 Multifrequency admittance based earth fault protection MFADPSDE ANSI 67NYH 553 4 2 10 ...

Page 14: ...on 920 4 6 1 Frequency protection FRPFRQ ANSI 81 920 4 6 2 Load shedding and restoration LSHDPFRQ ANSI 81LSH 928 4 7 Impedance protection 940 4 7 1 Distance protection DSTPDIS ANSI 21P 21N 940 4 7 2 Out of step OOSRPSB ANSI 78PS 1005 4 7 3 Three phase underexcitation protection UEXPDIS ANSI 40 1015 4 7 4 Three phase underimpedance protection UZPDIS ANSI 21G 1026 4 7 5 Directional negative sequence...

Page 15: ...pacitor banks COLPTOC ANSI 51 37 86C 1109 4 12 2 Current unbalance protection for capacitor banks CUBPTOC ANSI 60N 1119 4 12 3 Three phase current unbalance protection for shunt capacitor banks HCUBPTOC ANSI 60P 1131 4 12 4 Shunt capacitor bank switching resonance protection current based SRCPTOC ANSI 55ITHD 1142 4 12 5 Compensated neutral unbalance voltage protection CNUPTOV ANSI 59NU 1148 5 Prot...

Page 16: ...nce fault detection PHIZ ANSI HIZ 1179 5 4 1 Identification 1179 5 4 2 Function block 1179 5 4 3 Functionality 1179 5 4 4 Analog channel configuration 1179 5 4 5 Operation principle 1180 5 4 6 Application 1182 5 4 7 Signals 1182 5 4 8 PHIZ Settings 1183 5 4 9 PHIZ Monitored data 1183 5 5 Binary signal transfer BSTGAPC ANSI BST 1184 5 5 1 Identification 1184 5 5 2 Function block 1184 5 5 3 Function...

Page 17: ...1 Identification 1222 5 8 2 Function block 1222 5 8 3 Functionality 1223 5 8 4 Analog channel configuration 1223 5 8 5 Operation principle 1224 5 8 6 Application 1226 5 8 7 Signals 1227 5 8 8 CVPSOF Settings 1228 5 8 9 CVPSOF Monitored data 1229 5 8 10 Technical data 1230 5 9 Local acceleration logic DSTPLAL ANSI 21LAL 1230 5 9 1 Identification 1230 5 9 2 Function block 1230 5 9 3 Functionality 12...

Page 18: ...tionality 1265 5 12 4 Analog channel configuration 1266 5 12 5 Operation principle 1266 5 12 6 Application 1269 5 12 7 Signals 1271 5 12 8 CRWPSCH Settings 1272 5 12 9 CRWPSCH Monitored data 1272 5 12 10 Technical data 1273 5 13 Current reversal and weak end infeed logic for residual overcurrent RCRWPSCH ANSI 85 67G N CREV WEI 1274 5 13 1 Identification 1274 5 13 2 Function block 1274 5 13 3 Funct...

Page 19: ...6 3 Functionality 1294 5 16 4 Analog channel configuration 1295 5 16 5 Operation principle 1295 5 16 6 Application 1297 5 16 7 Signals 1299 5 16 8 Settings 1299 5 16 9 Monitored data 1300 5 16 10 Technical data 1300 6 Supervision functions 1302 6 1 Trip circuit supervision TCSSCBR ANSI TCM 1302 6 1 1 Identification 1302 6 1 2 Function block 1302 6 1 3 Functionality 1302 6 1 4 Operation principle 1...

Page 20: ...PC ANSI PCS 1326 6 4 1 Identification 1326 6 4 2 Function block 1327 6 4 3 Functionality 1327 6 4 4 Operation principle 1327 6 4 5 Application 1328 6 4 6 Signals 1330 6 4 7 PCSITPC Settings 1330 6 4 8 PCSITPC Monitored data 1330 6 5 Fuse failure supervision SEQSPVC ANSI VCM 60 1331 6 5 1 Identification 1331 6 5 2 Function block 1331 6 5 3 Functionality 1331 6 5 4 Analog channel configuration 1331 ...

Page 21: ... 6 Application 1348 6 8 7 Signals 1350 6 8 8 MSVPR Settings 1350 6 8 9 MSVPR Monitored data 1351 6 8 10 Technical data 1351 6 9 Current circuit supervision for transformers CTSRCTF ANSI CCM 3I I2 1352 6 9 1 Identification 1352 6 9 2 Function block 1352 6 9 3 Functionality 1352 6 9 4 Analog channel configuration 1353 6 9 5 Operation principle 1353 6 9 6 Application 1355 6 9 7 Signals 1356 6 9 8 CTS...

Page 22: ...1383 7 3 4 Analog channel configuration 1383 7 3 5 Operation principle 1384 7 3 6 Application 1391 7 3 7 Signals 1394 7 3 8 HSARSPTR Settings 1395 7 3 9 HSARSPTR Monitored data 1397 7 3 10 Technical data 1397 7 4 Cable fault detection RCFD ANSI CFD 1398 7 4 1 Identification 1398 7 4 2 Function block 1398 7 4 3 Functionality 1398 7 4 4 Analog input configuration 1398 7 4 5 Operation principle 1399 ...

Page 23: ...2 I0 1470 8 1 12 Sequence voltage measurement VSMSQI ANSI V1 V2 V0 1476 8 1 13 Three phase power and energy measurement PEMMXU ANSI P E 1481 8 2 Disturbance recorder common functionality RDRE ANSI DFR 1486 8 2 1 Identification 1486 8 2 2 Function block 1486 8 2 3 Functionality 1487 8 2 4 Configuration 1492 8 2 5 Application 1493 8 2 6 Signals 1493 8 2 7 Settings 1493 8 2 8 Monitored data 1494 8 3 ...

Page 24: ...ctionality 1520 9 2 4 Operation principle 1521 9 2 5 Application 1529 9 2 6 Signals 1531 9 2 7 P3SXSWI Settings 1534 9 2 8 P3SXSWI Monitored data 1535 9 2 9 Technical revision history 1535 9 3 Three state disconnector position indication P3SSXSWI ANSI 29DS GS 1536 9 3 1 Identification 1536 9 3 2 Function block 1536 9 3 3 Functionality 1536 9 3 4 Operation principle 1536 9 3 5 Application 1537 9 3 ...

Page 25: ... 6 7 Signals 1580 9 6 8 ASGCSYN Settings 1582 9 6 9 ASGCSYN Monitored data 1584 9 6 10 Technical data 1586 9 7 Autosynchronizer for network breaker ASNSCSYN ANSI 25AUTOSYNCBT T 1586 9 7 1 Identification 1586 9 7 2 Function block 1586 9 7 3 Functionality 1587 9 7 4 Analog input configuration 1587 9 7 5 Operation principle 1588 9 7 6 Application 1599 9 7 7 Signals 1601 9 7 8 ASNSCSYN Settings 1603 9...

Page 26: ...0 10 Technical data 1729 9 10 11 Technical revision history 1729 9 11 Petersen coil controller PASANCR ANSI 90 1730 9 11 1 Identification 1730 9 11 2 Function block 1730 9 11 3 Functionality 1730 9 11 4 Analog channel configuration 1731 9 11 5 Controller connections 1731 9 11 6 Operation principle 1733 9 11 7 Application 1744 9 11 8 Commissioning 1745 9 11 9 Signals 1747 9 11 10 PASANCR Settings 1...

Page 27: ...cs VHMHAI ANSI PQM VTHD VDC 1820 10 2 1 Identification 1820 10 2 2 Function block 1820 10 2 3 Functionality 1820 10 2 4 Analog channel configuration 1821 10 2 5 Operation principle 1821 10 2 6 Application 1824 10 2 7 Signals 1824 10 2 8 Settings 1827 10 2 9 Monitored data 1827 10 2 10 Technical data 1829 10 3 Voltage variation PHQVVR ANSI PQMV SWE SAG INT 1829 10 3 1 Identification 1829 10 3 2 Fun...

Page 28: ...1 3 2 IDMT curves for undervoltage protection 1902 11 4 Frequency measurement and protection 1906 11 5 Frequency adaptivity and generator start up protection 1907 11 6 Measurement modes 1908 11 7 Calculated measurements 1910 11 8 Test mode 1911 11 8 1 Functionality 1912 11 8 2 Application configuration and Test mode 1912 11 8 3 Control mode 1913 11 8 4 Application configuration and Control mode 19...

Page 29: ...14 Technical data 1940 15 Protection relay and functionality tests 1949 16 Applicable standards and regulations 1953 17 Glossary 1954 Contents REX640 Technical Manual 29 ...

Page 30: ...g normal service 1 2 Intended audience This manual addresses system engineers and installation and commissioning personnel who use technical data during engineering installation and commissioning and in normal service The system engineer must have a thorough knowledge of protection systems protection equipment protection functions and the configured functional logic in the protection relays The in...

Page 31: ...re modification instructions Modification sales guideline Figure 1 The intended use of documents during the product life cycle 1 3 2 Document revision history Document revision date Product connectivity level History A 2018 12 14 PCL1 First release B 2019 03 27 PCL1 Content updated C 2019 08 15 PCL1 Content updated D 2020 02 13 PCL2 Content updated to correspond to the prod uct connectivity level ...

Page 32: ...could result in electrical shock The warning icon indicates the presence of a hazard which could result in personal injury The caution icon indicates important information or warning 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 importa...

Page 33: ...d with quotation marks The corresponding parameter values are On and Off Input output messages and monitored data names are shown in Courier font When the function starts the START output is set to TRUE Values of quantities are expressed with a number and an SI unit The corresponding imperial units may be given in parentheses This document assumes that the parameter setting visibility is Advanced ...

Page 34: ...e directional overcurrent protection low stage DPHLPDOC 3I 67P 51P 1 Three phase directional overcurrent protection high stage DPHHPDOC 3I 67P 51P 2 Non directional earth fault protection low stage EFLPTOC Io 51G 51N 1 Non directional earth fault protection high stage EFHPTOC Io 51N 2 Non directional earth fault protection instantaneous stage EFIPTOC Io 50G 50N Directional earth fault protection l...

Page 35: ...CUBPTOC 3dI C 60P Shunt capacitor bank switching resonance protection current based SRCPTOC TD 55ITHD Compensated neutral unbalance voltage protection CNUPTOV CNU 59NU Directional negative sequence overcurrent protection DNSPDOC I2 67Q Low voltage ride through protection LVRTPTUV UU 27RT Voltage vector shift protection VVSPPAM VS 78VS Directional reactive power undervoltage protection DQPTUV Q 3U ...

Page 36: ...n HREFPDIF dIoHi 87NHI High impedance differential protection for phase A HIAPDIF dHi_A 87_A High impedance differential protection for phase B HIBPDIF dHi_B 87_B High impedance differential protection for phase C HICPDIF dHi_C 87_C Circuit breaker failure protection CCBRBRF 3I Io BF 50BF Three phase inrush detector INRPHAR 3I2f 68HB Master trip TRPPTRC Master Trip 94 86 Arc protection ARCSARC ARC...

Page 37: ...hp T 26 49HS Trip circuit supervision TCSSCBR TCS TCM Current circuit supervision CCSPVC MCS 3I CCM Current circuit supervision for transformers CTSRCTF MCS 3I I2 CCM 3I I2 Current transformer supervision for high impedance protec tion scheme for phase A HZCCASPVC MCS I_A CCM_A Current transformer supervision for high impedance protec tion scheme for phase B HZCCBSPVC MCS I_B CCM_B Current transfo...

Page 38: ...EDPTRC Individual virtual LED control LED LED LED Logging functions Disturbance recorder common functionality RDRE DR RDRE Disturbance recorder analog channels 1 12 A1RADR A1RADR A1RADR Disturbance recorder analog channels 13 24 A2RADR A2RADR A2RADR Disturbance recorder binary channels 1 32 B1RBDR B1RBDR B1RBDR Disturbance recorder binary channels 33 64 B2RBDR B2RBDR B2RBDR Fault recorder FLTRFRC ...

Page 39: ... 62TPS Minimum pulse timer minutes resolution two channels TPMGAPC TPM 62TPM Pulse counter for energy measurement PCGAPC PCGAPC PCGAPC Pulse timer eight channels PTGAPC PT 62PT Time delay off eight channels TOFGAPC TOF 62TOF Time delay on eight channels TONGAPC TON 62TON Daily timer DTMGAPC DTM DTM Calendar function CALGAPC CAL CAL SR flip flop eight channels nonvolatile SRGAPC SR SR Boolean value...

Page 40: ...measured value information GOOSERCV_MV GOOSERCV_MV GOOSERCV_MV Received GOOSE 8 bit integer value information GOOSERCV_INT8 GOOSERCV_INT8 GOOSERCV_INT8 Received GOOSE 32 bit integer value information GOOSERCV_INT32 GOOSERCV_INT32 GOOSERCV_INT32 Received GOOSE interlocking information GOOSERCV_INTL GOOSERCV_INTL GOOSERCV_INTL Received GOOSE measured value phasor information GOOSERCV_CMV GOOSERCV_CM...

Page 41: ...32GAPC SETI32GAPC SETI32GAPC 16 settable real values SETRGAPC SETRGAPC SETRGAPC Boolean to integer 32 bit conversion T_B16_TO_I32 T_B16_TO_I32 T_B16_TO_I32 Integer 32 bit to boolean conversion T_I32_TO_B16 T_I32_TO_B16 T_I32_TO_B16 Integer 32 bit to real conversion T_I32_TO_R T_I32_TO_R T_I32_TO_R Real to integer 8 bit conversion T_R_TO_I8 T_R_TO_I8 T_R_TO_I8 Real to integer 32 bit conversion T_R_...

Page 42: ... device 2 1 1 PCM600 and relay connectivity package version Protection and Control IED Manager PCM600 Ver 2 12 or later REX640 Connectivity Package Ver 1 3 0 or later Download connectivity packages from the ABB Web site www abb com mediumvoltage or directly with Update Manager in PCM600 2 2 Relay hardware The relay includes a Ready LED on the power supply module that indicates the relay s status I...

Page 43: ...have one of the allocated modules in the slot The population order of the modules in the optional slots depends on the composition variant ordered In case the relay and the HMI will be exposed to harsh environmental conditions like high humidity chemicals or other corrosive agents we recommend using the conformal coated versions of both Contact the nearest ABB sales representative for more informa...

Page 44: ...I port 3 RJ 45 1 LD SFP 1 COM1002 1 RJ 45 LHMI port 2 LC 1 RJ 45 1 LD SFP COM1003 1 RJ 45 LHMI port 3 LC 1 LD SFP COM1004 1 RJ 45 LHMI port 2 RJ 45 1 LD SFP 1 RS 485 IRIG B 1 FO UART Table continues on the next page 1 Line distance line differential protection communication binary signal transfer optical multi mode or single mode LC small form factor pluggable transceiver SFP REX640 overview 1MRS7...

Page 45: ... 3 PO TCS 2 PO 3 SO 2 SSO PO Power Output SO Signal Output SPO Static Power Output SSO Static Signal Output The relay has a nonvolatile memory which does not need any periodical maintenance The nonvolatile memory stores all events recordings and logs to a memory which retains data if the relay loses its auxiliary supply 2 3 Local HMI The LHMI is used for setting monitoring and controlling the prot...

Page 46: ...enu bar on the top of the LHMI display The Home button indicates the relay s status at a glance In normal situations the Home button shows a steady green light Any other situation that requires the operator s attention is indicated with a flashing light a red light or a combination of these Table 4 Power supply module Ready LED and local HMI Home button LED State Power supply module Ready LED LHMI...

Page 47: ...en Yes Relay set to Test Mode Low frequency blinking green 2 High frequency blinking green 2 No The Operator pages can be used as such or customized according to the project s requirements using Graphical Display Editor in PCM600 The Engineer pages are fixed and cannot be customized 2 1 2 3 4 5 6 7 8 9 10 11 8 Figure 4 Menu bar elements 1 Bay name for the relay 2 Page name 3 Edit mode active param...

Page 48: ... Force Outputs Simulate Inputs View I O Send Events Secondary Injection Monitor ing Protection Measurement Di rection Coil Controller Commission ing 3 View GOOSE sending View GOOSE receiving View SMV sending View SMV receiving Relay Status Monitoring Clear Disturbance Records Alarms Device Information USB Actions 3 Available with the Petersen coil control application package REX640 overview 1MRS75...

Page 49: ... and the related processes It comprises a 7 inch color screen with capacitive touch sensing and a Home button at the bottom of the SHMI All features of standard HMI are also available in the SHMI The SHMI is an accessory for the relay which is fully operational even without the SHMI 1MRS759142 F REX640 overview REX640 Technical Manual 49 ...

Page 50: ...each REX640 within the system The area presenting a single switchgear bay has a small user configurable bay overview section and a virtual Home button showing the status of the connected relay By tapping the selected bay overview area the SHMI connects with the related REX640 and works as normal LHMI for that relay REX640 overview 1MRS759142 F 50 REX640 Technical Manual ...

Page 51: ...d voltage level extension 8 Bay overview area showing static or dynamic information for a bay and functioning as a navigation point to launch the HMI view for the respective relay user defined content 9 SHMI navigation page 10 Virtual Home button representing the status of the respective relay s physical Home button 11 Number of active alarms 12 Panel lineup overview showing the current status of ...

Page 52: ...hing light a red light or a combination of these SHMI s physical Home button has two operation modes On the SHMI navigation page the Home button indicates the combined status of all connected relays If multiple relays have different statuses the Home button shows the indication with the highest priority On the HMI view the Home button indicates the status of the respective relay as described in Fi...

Page 53: ...ts The relay communication module has a dedicated port where the LHMI is connected using an RJ 45 connector and a CAT 6 S FTP galvanic cable The HMI can be connected to the relay also via station communication network if a longer distance is required between the relay and the HMI For more information see the installation manual Additionally the HMI contains one Ethernet service port with an RJ 45 ...

Page 54: ...s Device Monitoring Used to navigate to monitoring information self supervision single line diagram or clear pages Information Self supervision Single Line Diagram Clear Change Password About Measurements Measurements Used to navigate to the measurements or phasor diagrams Phasor Diagrams Recordings Events Used to view the events disturbance records fault records load profile records and alarms Di...

Page 55: ...g to any one of these roles Each user account can be mapped to a maximum of eight roles The factory default passwords can be changed with Administrator user rights or by the users themselves Relay user passwords can be changed using the LHMI IED Users in PCM600 or the WHMI Only Administrator can create user accounts and update the roles to rights mapping Administrator can also reset the passwords ...

Page 56: ...es communication networks can be separated based on the dominant user s needs For example one IP address can serve the dispatchers and the other one can serve the service engineers needs The IEC 61850 protocol is a core part of the relay as the protection and control application is fully based on standard modelling The relay supports Edition 2 and Edition 1 versions of the standard With Edition 2 ...

Page 57: ...ority Clear AD userlist 0 False 1 True 0 False Clear Active Direc tory user list FTP write access 0 Off 1 On 1 On FTP write access MMS write access 0 Off 1 On 1 On MMS write access HTTPS write access 0 Off 1 On 1 On HTTPS write access FTP write access 0 Off 1 On 1 On FTP write access MMS write access 0 Off 1 On 1 On MMS write access HTTPS write access 0 Off 1 On 1 On HTTPS write access FTP write a...

Page 58: ...ysteresis 3 1 3 Network1 address settings Table 9 Non group settings Parameter Values Range Unit Step Default Description IP address 192 168 2 10 IP address for Net work1 Subnet mask 255 255 255 0 Subnet mask for Network1 Default gateway 192 168 2 1 Default gateway for Network1 Mac address XX XX XX XX XX XX Mac address for Network1 3 1 4 Network2 address settings Table 10 Non group settings Parame...

Page 59: ...er Blocking mode 1 Freeze timer 2 Block all 3 Block OPERATE output 1 Freeze timer Behaviour for func tion BLOCK inputs Bay name REX640 Bay name in system IDMT Sat point 10 50 I I 1 50 Overcurrent IDMT saturation point Frequency adaptivi ty 0 Disable 1 Enable 0 Disable Enabling frequency adaptivity SMV Max Delay 0 2 2 ms 1 3 3 ms 2 5 4 ms 3 6 5 ms 4 7 6 ms 1 3 3 ms SMV Maximum al lowed delay Test m...

Page 60: ...l mode setting of a control function is set to sbo with enhanced security the confirmation dialog box always opens regardless of the Breaker operation setting value Delayed close If the parameter Close delay mode in Configuration Control LHMI is set to In use a timer is started after tapping the close button and accepting the possible confirmation dialog Close operation is performed only after the...

Page 61: ... char 1 4 Start frame delay in chars End delay 0 20 char 1 4 End frame delay in chars DevFunType 0 255 1 9 Device Function Type UsrFunType 0 255 1 10 Function type for User Class 2 Frame UsrInfNo 0 255 1 230 Information Num ber for User Class2 Frame Class1Priority 0 Ev High 1 Ev DR Equal 2 DR High 0 Ev High Class 1 data send ing priority rela tionship between Events and Disturb ance Recorder data ...

Page 62: ...me 4 5 Standard frame 5 6 Private frame 6 7 Private frame 7 1 Not in use Active Class2 Frame 4 Class1OvInd 0 No indication 1 Both edges 2 Rising edge 2 Rising edge Overflow Indication Class1OvFType 0 255 1 10 Function Type for Class 1 overflow in dication Class1OvInfNo 0 255 1 255 Information Num ber for Class 1 over flow indication Class1OvBackOff 0 500 1 500 Backoff Range for Class1 buffer GI Op...

Page 63: ...ransmitted frames INT32 1 2147483646 Transmitted frames 3 1 11 IEC 101 104 General settings Table 17 Non group settings Parameter Values Range Unit Step Default Description Operation 1 on 5 off 5 off Selects if this pro tocol instance is enabled or disabled Port 3 IEC104 Ethernet 3 IEC104 Ethernet Port selection Mapping select 1 2 1 1 Mapping select ClientIP 0 0 0 0 IP address of the client TCP Po...

Page 64: ...0 Read by master Counter reporting after freeze Freeze mode 0 Not in use 1 Freeze only 2 Freeze and Reset 0 Not in use Freezing mode for externally triggered integrated totals TX window k 1 20 1 12 IEC60870 5 104 transmit window k RX window w 1 20 1 8 IEC60870 5 104 re ceive window w TX timeout t1 1 2147483647 ms 1 30000 IEC60870 5 104 transmit timeout t1 RX timeout t2 1 2147483647 ms 1 10000 IEC6...

Page 65: ... statistics thresholds settings Table 19 Non group settings Parameter Values Range Unit Step Default Description Unexpected Msgs 1 65535 1 3 Security statistics threshold for unex pected messages Auth failures 1 65535 1 5 Security statistics threshold for au thorization failures Authn failures 1 65535 1 5 Security statistics threshold for au thentication fail ures Reply timeouts 1 65535 1 3 Securi...

Page 66: ...r failed update key changes 3 1 14 IEC 101 104 Monitored data Table 20 Monitored data Name Type Values Range Unit Description Customization Mode Enum 0 Off Normal 1 By Parameter 2 By File Protocol Customization Mode Reset counters BOOLEAN 0 False 1 True Reset counters Received frames INT32 1 2147483646 Received frames Transmitted frames INT32 1 2147483646 Transmitted frames Physical errors INT32 1...

Page 67: ...istics coun ter for discarded mes sages Err Msgs Tx Cnt INT32 0 2147483646 Security statistics coun ter error messages sent Err Msgs Rx Cnt INT32 0 2147483646 Security statistics coun ter error messages re ceived Successful Authn Cnt INT32 0 2147483646 Security statistics coun ter for successful au thentications Session Key Chg Cnt INT32 0 2147483646 Security statistics coun ter for session key ch...

Page 68: ...ys be RTU TCP port 1 65535 1 502 Defines the listen ing port for the Modbus TCP server Default 502 Parity 0 none 1 odd 2 even 2 even Parity for the serial connection Start delay 0 20 1 4 Start delay in char acter times for seri al connection End delay 0 20 1 4 End delay in charac ter times for serial connections CRC order 0 Hi Lo 1 Lo Hi 0 Hi Lo Selects between normal or swap ped byte order for ch...

Page 69: ... available on 4x memory area ControlStructPWd 3 Password for con trol operations us ing Control Struct mechanism which is available on 4x memory area ControlStructPWd 4 Password for con trol operations us ing Control Struct mechanism which is available on 4x memory area ControlStructPWd 5 Password for con trol operations us ing Control Struct mechanism which is available on 4x memory area ControlS...

Page 70: ...o sockets available CnReject unregistered INT32 1 2147483646 Connection rejected due to unregistered cli ent 3 1 19 DNP 3 0 Settings Table 25 Non group settings Parameter Values Range Unit Step Default Description Operation 1 on 5 off 5 off Operation Off On Port 1 COM 1 2 COM 2 3 Ethernet TCP 1 4 Ethernet TCP UDP 1 5 Ethernet UDP 1 3 Ethernet TCP 1 Communication in terface selection Unit address 0...

Page 71: ...O 100 65535 ms 1 3000 Data link confirm timeout Data link retries 0 65535 1 3 Data link retries count Data link Rx to Tx delay 0 255 ms 1 0 Turnaround trans mission delay Data link inter char delay 0 20 char 1 4 Inter character de lay for incoming messages App layer confirm 1 Disable 2 Enable 1 Disable Application layer confirm mode App UR confirm TO 100 65535 ms 1 5000 Application layer confirm a...

Page 72: ...BI event time 1 DBI event 2 DBI event with time Default Var Obj 20 1 1 32bit Cnt 2 2 16bit Cnt 5 5 32bit Cnt no flag 6 6 16bit Cnt no flag 2 2 16bit Cnt 1 32 bit counter 2 16 bit counter 5 32 bit counter without flag 6 16 bit counter without flag Default Var Obj 21 1 1 32bit FrzCnt 2 2 16bit FrzCnt 5 5 32bit FrzCnt time 6 6 16bit FrzCnt time 9 9 32bit FrzCnt noflag 10 10 16bit FrzCnt noflag 6 6 16...

Page 73: ... 4 4 AO double 2 2 16bit AO 1 32 bit AO 2 16 bit AO 3 AO float 4 AO double Default Var Obj 42 1 1 32bit AO evt 2 2 16bit AO evt 3 3 32bit AO evt time 4 4 16bit AO evt time 5 5 float AO evt 6 6 double AO evt 7 7 float AO evt time 8 8 double AO evt time 4 4 16bit AO evt time 1 32 bit AO event 2 16 bit AO event 3 32 bit AO event with time 4 16 bit AO event with time 5 float AO event 6 double AO event...

Page 74: ...ication rekeys threshold Max Err Msg Tx Thres 1 65335 1 10 Maximum error messages sent threshold Event Class Obj 122 1 1 2 2 3 3 4 1 2 5 1 3 6 2 3 7 1 2 3 1 1 Event Class for Obj 122 Default Var Obj 122 1 32bit SecStat evt 2 32bit SecStat evt time 1 32bit SecStat evt 1 32bit Secure Statistics event 2 32bit Secure Sta tistics event with time Clear User List 0 False 1 True 0 False Clear DNP Secure a...

Page 75: ...hold for suc cessful authentica tions Sesn key Chg 1 65535 1 10 Security statistics threshold for ses sion key changes Failed Sesn key Chgs 1 65535 1 5 Security statistics threshold for failed session key changes Upd key Chgs 1 65535 1 1 Security statistics threshold for up date key changes Failed Upd key Chgs 1 65535 1 1 Security statistics threshold for failed update key changes 3 1 22 DNP 3 0 M...

Page 76: ... es received Discarded Msgs Cnt INT32 0 2147483646 Security statistics coun ter for discarded mes sages Err Msgs Tx Cnt INT32 0 2147483646 Security statistics coun ter error messages sent Err Msgs Rx Cnt INT32 0 2147483646 Security statistics coun ter error messages re ceived Successful Authn Cnt INT32 0 2147483646 Security statistics coun ter for successful au thentications Session Key Chg Cnt IN...

Page 77: ...83646 CD lost Collision INT32 1 2147483646 Collision CTS Timeout INT32 1 2147483646 CTS Timeout Transmission timeout INT32 1 2147483646 Transmission timeout Parity errors INT32 1 2147483646 Number of parity errors Overrun errors INT32 1 2147483646 Number of overrun er rors Framing errors INT32 1 2147483646 Number of framing er rors Reset counters BOOLEAN 0 False 1 True Resets counters 3 1 26 COM2 ...

Page 78: ...ed INT32 1 2147483646 Number of transmitted frames CD lost INT32 1 2147483646 CD lost Collision INT32 1 2147483646 Collision CTS Timeout INT32 1 2147483646 CTS Timeout Transmission timeout INT32 1 2147483646 Transmission timeout Parity errors INT32 1 2147483646 Number of parity errors Overrun errors INT32 1 2147483646 Number of overrun er rors Framing errors INT32 1 2147483646 Number of framing er...

Page 79: ...itch functions with either another SMV stream or local measurements The SMV stream quality along with other Application Configuration logic can be used for switching between measurement sources The IEC 61850 communication implementation supports all monitoring and control functions Additionally parameter settings disturbance recordings and fault records can be accessed using the IEC 61850 protocol...

Page 80: ...f healing ring topology the network topology must be a ring It is essential that the external switches in the network support the RSTP protocol and that it is enabled in the switches Otherwise connecting the ring topology can cause problems to the network The protection relay itself does not support link down detection or RSTP The ring recovery process is based on the aging of the MAC addresses an...

Page 81: ...t effective redundancy Thus each device incorporates a switch element that forwards frames from port to port IEC 62439 3 2012 cancels and replaces the first edition published in 2010 These standard versions are also referred to as IEC 62439 3 Edition 1 and IEC 62439 3 Edition 2 The protection relay supports IEC 62439 3 2016 Edition 3 and IEC 62439 3 2012 and it is not compatible with IEC 62439 3 2...

Page 82: ... protection relay s interlink port HSR HSR applies the PRP principle of parallel operation to a single ring treating the two directions as two virtual LANs For each frame sent a node DAN sends two frames one over each port Both frames circulate in opposite directions over the ring and each node forwards the frames it receives from one port to the other When the originating node receives a frame se...

Page 83: ...rofile of IEC 61850 9 2 to facilitate implementation and enable interoperability Process bus is used for distributing process data from the primary circuit to all process bus compatible devices in the local network in a real time manner The data can then be processed by any protection relay to perform different protection automation and control functions Redundant SMV streams are also supported by...

Page 84: ...using the IEC 61850 9 2 LE protocol which uses the same physical Ethernet network as the IEC 61850 8 1 station bus One example application is sharing the measured busbar voltage from one or several REX640 relays with the other REX640 relays This can be done even for a double busbar switchgear installation using automatic 9 2 stream selection based on the bus disconnectors physical position REX640 ...

Page 85: ...ust use explicit FTPS 3 2 6 Communication services control 3 2 6 1 Ethernet ports The protection relay allows the use of a secondary IP address for the station ports on the communication modules COM1001 COM1003 This secondary IP network is assigned to a single Ethernet port and can be used to make separate networks for different communication protocols or for example a separate service network for...

Page 86: ...ault settings and all Ethernet ports are assigned to the same IP address used in the Network 1 address menu Configuration Communication Ethernet Network 1 If Network 2 is taken into use by the setting Enable True requires reboot the interlink port X3 of the COM module is assigned to this second network using the IP address and subnet parameters in the Network 2 address menu Configuration Communica...

Page 87: ...ck different protocols for different network interfaces in the protection relay using the parameters in Configuration Communication Protocols Network1 Configuration Communication Protocols Network2 and Configuration Communication Protocols HMI Port All protocols are allowed for each network by default and can be separately disabled 1MRS759142 F Basic functions REX640 Technical Manual 87 ...

Page 88: ...MMS Configuration Communication Proto cols Network1 DNP Off Denies DNP3 On Default Allows DNP3 Configuration Communication Proto cols Network2 DNP Off Denies DNP3 On Default Allows DNP3 Configuration Communication Proto cols Network1 Modbus Off Denies Modbus On Default Allows Modbus Configuration Communication Proto cols Network2 Modbus Off Denies Modbus On Default Allows Modbus Configuration Comm...

Page 89: ...cess allowed for Network 2 Configuration Authorization Net work2 HTTPS write access Off HTTPS write access denied for Network 2 On Default HTTPS write access allowed for Network 2 Configuration Authoriza tion HMI FTP write access Off FTP write access denied for the HMI port On Default FTP write access allowed for the HMI port Configuration Authoriza tion HMI MMS write access Off IEC 61850 MMS writ...

Page 90: ...n block 3 2 8 2 Functionality The serial port supervision function SERLCCH represents one serial communication port driver Depending on the hardware configuration the protection relay can be equipped with two UART based serial communication ports The communication ports can be both galvanic RS 485 or one port could be fiber optic The protection relay uses the ports for serial communication protoco...

Page 91: ...hardware option Serial channels can be found on communication boards COM1004 COM1005 X7 is the fiber optic interface Only driver COM2 can be configured into fiber optic mode X8 is the RS 485 IRIG B interface Both drivers COM1 and COM2 can be configured to this interface COM1 and COM2 can act as two RS 485 2 wire links or alternatively COM1 can act as one single RS 485 4 wire link Both ports are ga...

Page 92: ...nout for socket on communication board Table 39 LED configuration COM1004 COM1005 LED Description X1 X1 LANA X2 X2 LANB X6 X6 LD X7 TX FO UART X8 TX RS 485 COM2 X8 TX RS 485 COM1 IRIG B IRIG B Basic functions 1MRS759142 F 92 REX640 Technical Manual ...

Page 93: ... are possible through this switch If the switch is in OFF position bias and termination are disabled and in ON position they are enabled ON OFF Figure 18 DIP switches on the COM1004 COM1005 cards Table 40 Bias and termination DIP switch Switch Signal X8 pin Type 1 RS485_A1 8 Bias 2 RS485_A1 RS485_B1 Bus termination 3 RS485_B1 7 Bias 4 RS485_A2 10 Bias 5 RS485_A2 RS485_B2 Bus termination 6 RS485_B2...

Page 94: ...erroneous frames received Protocol specific frames can be based on timing for exam ple Modbus RTU or on special start and stop characters for example Modbus ASCII Frames discarded Counts all protocol specific erroneous frames received If the driver detects an error while receiving a frame the whole frame is automatically discarded This also means that the protocol in question never receives a faul...

Page 95: ...ing Communication Management in PCM600 There are two mapping sets Mapping 1 and Mapping 2 and either can be used Setting parameter Mapping selection points to the mapping set used Several Modbus protocol instances can point to the same mapping set For more information on the Modbus server protocol see the Modbus communication protocol manual 3 2 14 DNP3 protocol DNPLPRT 3 2 14 1 Function block DNP...

Page 96: ...ude communication interface assignment for the instance that is serial communication port 1 or 2 An IEC 60870 5 103 server protocol instance is activated if the function block instance is added to the application configuration The setting Operation should be On and setting Serial port should have the communication interface assignment The STATUS output of the function block is active if IEC 60870 ...

Page 97: ...ut can be configured for external counter freezing By default no IEC 60870 5 104 data objects are mapped to the protocol instance Protocol data can be added and modified using Communication Management in PCM600 For more information on the IEC 60870 5 104 server protocol see the IEC 60870 5 104 communication protocol manual 3 3 Self supervision The protection relay s extensive self supervision syst...

Page 98: ... under Relay Status page The self supervision status is indicated with Internal Fault Warning and All OK LEDs In normal operation All OK LED is lit The selfsupervision also controls the status of IRF output relay The IRF output relay is energized under normal conditions and de energized under internal fault conditions Figure 23 Relay self supervision status on local HMI On the WHMI the self superv...

Page 99: ... de energized and contacts are released for the internal fault The protection relay continues to perform internal tests during the fault situation If the internal fault disappears the fault indication LEDs stop flashing and the protection relay returns to the normal service state One possible cause for an internal fault situation is a so called soft error The soft error is a probabilistic phenomen...

Page 100: ...ion about the fault and recovery options can be accessed by tapping More Information Figure 26 Internal fault state indicated with red LED More Information shows all active faults and the corresponding fault codes In addition a recovery procedure is described Figure 27 More information about the fault Basic functions 1MRS759142 F 100 REX640 Technical Manual ...

Page 101: ... restore or re write configuration using PCM600 Internal Fault System error 2 Start up error Missing order num ber No No Yes Do factory restore If not recovered contact your nearest ABB representative to check the next possible corrective action Internal Fault System error 2 Start up error FPGA HW error CPU module Yes Yes 3 No Restart the relay If recov ered by restarting contin ue relay normal op...

Page 102: ... If not recover by restarting replace the relay Internal Fault LHMI module 79 Start up error EE PROM error in LHMI module The fault indication may not be seen on the LHMI during the fault No No Yes Restart the relay If recov ered by restarting contin ue relay normal operation If not recover by restarting check LHMI connection ca ble and connection to be proberly fixed If then not recovered by rest...

Page 103: ...odule Internal Fault COM card error 116 Runtime error Er ror in the COM card Yes Yes 3 No Restart the relay If recov ered by restarting contin ue relay normal operation If not recover by restarting exchange the communica tion module in slot X000 Internal Fault SO relay s Slot C 10 Runtime error Faulty Signal Out put relay s in card located in slot C Yes Yes 3 No Check wirings Restart the relay If ...

Page 104: ... Internal Fault PO relay s Slot C 20 Runtime error Faulty Power Out put relay s in card located in slot C Yes Yes 3 No Check wirings Restart the relay If recovered by re starting continue relay nor mal operation If not recov er by restarting exchange the hardware module in slot C Internal Fault PO relay s Slot E 21 Runtime error Faulty Power Out put relay s in card located in slot E Yes Yes 3 No C...

Page 105: ...t E 31 Start up error Card in slot E is wrong type is missing does not belong to original configu ration or card firm ware is faulty No No Yes Check that the card in slot E is proper type and prop erly installed Then restart the relay If does not then recover by restarting it is hardware module failure most likely in question Ex change the hardware mod ule in slot E Internal Fault Conf error Slot ...

Page 106: ...ly installed Then restart the relay If does not then recover by restarting it is hardware module failure most likely in question Ex change the hardware mod ule in slot A1 Internal Fault Card error Slot C 40 Card in slot C is faulty Yes No Yes Exchange the hardware module in slot C Internal Fault Card error Slot E 41 Card in slot E is faulty Yes No Yes Exchange the hardware module in slot E Interna...

Page 107: ...and code so that it can be provided to ABB customer service See the operation manual for more information on reading internal log files from the relay On the LHMI an active warning is indicated with a yellow LED More information about the warning and recovery options can be accessed by tapping More Information Figure 29 Active warning on local HMI More information shows all active warnings and cor...

Page 108: ...r in the DNP3 communication Dataset warning 24 Error in the Data set s Report cont warning 25 Error in the Report control block s GOOSE contr warning 26 Error in the GOOSE control block s SCL config warning 27 Error in the SCL configuration file or the file is missing Logic warning 28 SMT logic warning 29 GOOSE input warning 30 ACT warning 31 Analog channel configuration warn ing GOOSE rec warning...

Page 109: ...ror occurred in RTD module located in slot C 3 3 3 Power supply module Ready LED and HMI Home button LED Both power supply module Ready LED and LHMI Home button LED visualize the self supervision state of the relay Table 45 shows how these states are indicated Table 45 Power supply module Ready LED and local HMI Home button LED State Power supply module Ready LED LHMI Home button Alarm acknowledge...

Page 110: ... into two subparts dependability and security The dependability can be described as the protection scheme s ability to operate when required The security can be described as the protection scheme s ability to refrain from operating when not required The protection scheme fail safe principle is typically related to satisfying these two performance criteria Depending on the requirements set to the e...

Page 111: ... via an emergency switch and in case the control voltage disappears In case of a temporary internal relay fault the circuit breaker is immediately tripped before the relay recovers from the situation In case the IRF output relay is directly connected to the undervoltage trip coil circuit the output s performance figures make and break values must be checked U TC1 Q0 AUX POWER A1 F1 Control Control...

Page 112: ...or feeder fail safe trip circuit principle example 3 A1 Protection relay ES Emergency stop Q0 Circuit breaker CB TO Protection relay trip output IRF Internal relay fault indication U CB undervoltage trip coil TC1 CB trip coil 1 K1 OFF delay time relay F1 Miniature circuit breaker In example 3 the fail safe approach aims at securing motor shutdown via an emergency switch and in case the control vol...

Page 113: ...witch and in case the control voltage disappears The adjacent panels provide backup for each other in internal relay fault situations In case of an internal relay fault the situation is noticed by the relay in the adjacent panel and the circuit breaker in the panel with the faulty relay is tripped after a preset time delay The additional time delay allows the relay to recover from the internal fau...

Page 114: ...f a relay fails The incomer panel relay indicates the start of selected protection functions This start signal is distributed to all load feeder panels If a relay in the load feeder panel indicates an IRF status the start signal of the incomer panel relay results in circuit breaker tripping This approach offers basic protection for a load feeder while the actual protection relay performs a self su...

Page 115: ...l Control A2 A1 TO F1 Q0 TO AUX POWER AUX POWER Figure 37 Redundant protection fail safe principle example 3 Q0 Circuit breaker CB A1 Protection relay 1 A2 Protection relay 2 TO Protection relay trip output TC1 CB trip coil 1 TC2 CB trip coil 2 F1 Miniature circuit breaker In example 3 the fail safe approach aims at securing circuit breaker tripping even if one of the redundant relays fails The sc...

Page 116: ...nt relays fails and in addition no single relay alone can cause the circuit breaker tripping The scheme is often referred to as the 2 out of 3 approach This approach allows service continuation while the failed relay is waiting for spare parts or a complete replacement The redundancy in this example covers relays and circuit breaker tripping coils but it can be expanded to auxiliary power supplies...

Page 117: ...e signals are internally connected to Device Status on WHMI Dashboard and the Device Status widget on the LHMI if the widget has been instantiated in the LHMI engineering phase LEDPTRC collects and combines phase information from different protection functions available as output signals OUT_ST_A _B _C and OUT_OPR_A _B _C There is also combined earth fault information collected from all the earth ...

Page 118: ...ction block 3 5 3 Functionality The virtual programmable LEDs are visible on the Programmable LEDs page in LHMI and on the WHMI dashboard Figure 41 Programmable LEDs page in LHMI Basic functions 1MRS759142 F 118 REX640 Technical Manual ...

Page 119: ...le of the Programmable LEDs page Each LED is seen in Application Configuration as an individual function block Each LED has a user editable description text for event description The state None OK Alarm of each LED can also be read under a common monitored data view for programmable LEDs The LED status also provides a means for resetting the individual LED via communication The LED can also be res...

Page 120: ...w F Follow Signal Flashing Similar to Follow S but instead the LED is flashing when the input is active Non latched Latched S Latched ON This mode is a latched function At the activation of the input signal the alarm shows a steady light After acknowledgement by the local operator pressing any key on the keypad the alarm disappears Activating signal LED Acknow Figure 46 Operating sequence Latched ...

Page 121: ...ble 47 Settings for LEDs 1 66 Parameter Values Range Unit Step Default Description Alarm colour 1 Green 2 Red 2 Red Colour for the alarm state of the LED Alarm mode 0 Follow S 1 Follow F 2 Latched S 3 LatchedAck F S 0 Follow S Alarm mode for the programma ble LED 3 5 6 Monitored data Table 48 Monitored data for LEDs 1 66 Name Type Values Range Unit Description Programmable LED n 1 Enum 0 None 1 Ok...

Page 122: ...nchronization 3 6 1 Time master supervision GNRLLTMS 3 6 1 1 Function block Figure 48 Function block 3 6 1 2 Functionality The protection relay has a disciplined RTC in hardware with a resolution of one nanosecond The clock can be either free running or synchronized to an external source The RTC is used to time stamp events recorded data disturbance recordings sampled measured values and various o...

Page 123: ...vide time master backup functionality Connect at least one measurement channel in Application Configuration in PCM600 either from the hardware AIM or SIM or from SMVRCV to ensure that the time system works correctly Line differential communication When using line differential communication between the protection relays the time synchronization messages can be received from the other line end prote...

Page 124: ...ased on the stored grandmasters list The alarm is activated when there are no clocks with capabilities equivalent to primary or secondary grandmaster clocks The warning is activated when a primary grandmaster clock is not available The grandmaster list can be Section 3 1MRS759142 E Basic functions 132 REX640 Technical Manual cleared using the Clear clock list setting for example if the grandmaster...

Page 125: ...r the protection relay Legacy protocols as time synchronization sources do not offer the best accuracy For better accuracy PTP SNTP or IRIG B time synchronization is recommended 3 6 1 3 Signals Table 50 GNRLLTMS Output signals Name Type Description ALARM BOOLEAN Alarm status for clock synchronization Al ways FALSE with Synch source set to None WARNING BOOLEAN Warning status for clock synchronizati...

Page 126: ...hronized by an external master FALSE if the clock has not been synchronized by an external master Table 53 IRIG B Output signals Name Type Description ALARM BOOLEAN Alarm status for clock synchronization TRUE if the signal has been lost for a minute Otherwise FALSE WARNING BOOLEAN Warning status for clock synchronization TRUE if the signal connection is lost FALSE if the relay is synchronized to a...

Page 127: ...scription ALARM BOOLEAN Alarm status for clock synchronization TRUE if the LD connection has been lost WARNING BOOLEAN Warning status for clock synchronization TRUE if the LD connection has been lost EXTCLKMSTR BOOLEAN Status of the protection relay s clock syn chronization TRUE if the clock has been synchronized to the LD partner 3 6 1 4 Settings Time format settings Table 56 Non group settings P...

Page 128: ... IED can not become a clock master Time master mode 1 Master with fi nite holdover 2 Master with in finite holdover 1 Master with fi nite holdover Device Time Master Mode Clear clock list 0 False 1 True 0 False Clears the stored master clock list Time Syn Src Tmm 1 65535 min 1 3 Time synchroniza tion timeout for legacy protocols as clock source Mod bus IEC103 IEC101 IEC104 and DNP Table 58 Non gro...

Page 129: ...on day week day 0 reserved 1 Monday 2 Tuesday 3 Wednesday 4 Thursday 5 Friday 6 Saturday 7 Sunday 0 reserved Daylight saving time on day of week DST off time hours 0 23 h 2 Daylight saving time off time hh DST off time mi nutes 0 59 min 0 Daylight saving time off time mm DST off date day 1 31 25 Daylight saving time off date dd mm DST off date month 1 January 2 February 3 March 4 April 5 May 6 Jun...

Page 130: ...running Time synchronization source Synch status Bool 0 Down 1 Up Time synchronization status Synch accuracy Int 0 128 Time synchronization accuracy Number of the significant bits in fraction of second PTP gm identity String PTP grand master clock identity according PTP standard PTP gm time Src Enum 1 Atomic clock 2 GPS 3 Terrestrial radio 4 PTP 5 NTP 6 Hand set 7 Other 8 Internal oscil PTP grand ...

Page 131: ...egorized as group settings inside application functions The customer can change the active setting group at run time The active setting group can be changed by a parameter or via binary inputs depending on the mode selected with the Configuration Setting Group SG operation mode setting The default value of all inputs is FALSE which makes it possible to use only the required number of inputs and le...

Page 132: ...s BI_SG_5 and BI_SG_6 Value of the SG_LOGIC_SEL output is TRUE For example six setting groups can be controlled with three binary inputs SG operation mode is set to Logic mode 2 and inputs BI_SG_2 and BI_SG_5 are connected together the same way as inputs BI_SG_3 and BI_SG_6 Table 63 SG operation mode Logic mode 1 Input BI_SG_2 BI_SG_3 BI_SG_4 BI_SG_5 BI_SG_6 Active group FALSE FALSE FALSE FALSE FA...

Page 133: ...process Control function com mand is blocked TRUE TRUE For more information see the Test mode section in this manual 3 7 2 3 Frequency adaptivity The FRQ_ADP_WARN output is active when full adaptation to the actual frequency is not reached or guaranteed The FRQ_ADP_FAIL output is active when no frequency source has sufficient amplitude and the nominal frequency window size is used in measurements ...

Page 134: ...s ac tive BI_SG3 BOOLEAN 0 Setting group 3 is ac tive BI_SG4 BOOLEAN 0 Setting group 4 is ac tive BI_SG5 BOOLEAN 0 Setting group 5 is ac tive BI_SG6 BOOLEAN 0 Setting group 6 is ac tive MOD_TEST BOOLEAN 0 Activation of test mode MOD_BLK BOOLEAN 0 Block test mode Table 68 PROTECTION Output signals Name Type Description SG_LOGIC_SEL BOOLEAN Logic selection for setting group SG_1_ACT BOOLEAN Setting ...

Page 135: ...l is by default realized through the R L button on the front panel The control via binary input can be enabled by setting the value of the LR control setting to Binary input The binary input control requires that the CONTROL function is instantiated in the product configuration Local Remote control supports multilevel access for control operations in substations according to the IEC 61850 standard...

Page 136: ...ion is made with R L button or CONTROL function block and IEC 61850 data object CTRL LLN0 LocSta When writing CTRL LLN0 LocSta IEC 61850 data object IEC 61850 command originator category station must be used by the client and remote IEC 61850 control access must be allowed by the relay station authority CTRL LLN0 LocSta data object value is retained in the nonvolatile memory The present control st...

Page 137: ...status Control access R L button CTRL LLN0 LocSta CTRL LLN0 MltLev L R state CTRL LLN0 LocKey HMI Local user IEC 61850 client 1 Local N A FALSE 1 x Remote N A FALSE 2 x Off N A FALSE 0 Table 72 Station authority L R using CONTROL function block L R control L R control status Control access Control FB input CTRL LLN0 LocSta CTRL LLN0 MltLev L R state CTRL LLN0 LocKey HMI Local user IEC 61850 client...

Page 138: ...using R L button or CONTROL function block IEC 61850 data object CTRL LLN0 LocSta and CONTROL function block input CTRL_STA are not applicable for this station authority level Table 73 Station authority level L R L R using R L button L R Control L R Control status Control access R L button CTRL LLN0 LocSta CTRL LLN0 MltLev L R state CTRL LLN0 LocKey HMI Local user IEC 61850 client1 Local N A FALSE...

Page 139: ...ock IEC 61850 data object CTRL LLN0 LocSta and CONTROL function block input CTRL_STA are applicable for this station authority level Station control access can be reserved by using R L button or CONTROL function block together with IEC 61850 data object CTRL LLN0 LocSta Table 75 Station authority level L S R using R L button L R Control L R Control status Control access R L button CTRL LLN0 LocS t...

Page 140: ...emote IEC 61850 station IEC 61850 remote IEC 61850 remote IEC 61850 remote IED IEC 61850 station IED IEC 61850 station IED IEC 61850 station L S LOCAL STATION S R IEC 61850 remote IEC 61850 remote IED IEC 61850 station IED IEC 61850 station OFF L S R Figure 54 Station authority is L S S R L S L S R When station authority level L S S R L S L S R is used control access can be selected using R L butt...

Page 141: ... 6 x x x CTRL_ALL 7 TRUE TRUE 5 x x 3 8 8 Control mode The function has two outputs BEH_TST and BEH_BLK which are activated in test mode according to Table 79 Table 79 Control mode Control mode Description Control BEH_BLK On Normal operation FALSE Blocked Control function commands blocked TRUE Off Control functions disabled FALSE For more information see the Test mode chapter in this manual 1 Stat...

Page 142: ...ontrol output Station REMOTE BOOLEAN Control output Remote ALL BOOLEAN Control output All BEH_BLK BOOLEAN Logical device CTRL block status BEH_TST BOOLEAN Logical device CTRL test status 3 8 10 Settings Table 82 Non group settings Parameter Values Range Unit Step Default Description LR control 1 LR key 2 Binary input 1 LR key LR control through LR key or bi nary input Station authority 1 L R 2 L S...

Page 143: ...local allowed 14 RL remote allowed 15 RL off 16 Function off 17 Function blocked 8 Command progress 19 Select timeout 20 Missing authority 21 Close not enabled 22 Open not enabled 23 Internal fault 24 Already close 25 Wrong client 26 RL station allowed 27 RL change 28 Abortion by trip 29 Reed not closed 30 Motor blocked 31 Motor wrong direc tion Latest command re sponse LR state Enum 0 Off 1 Local...

Page 144: ...ng period with for example binary input If Start duration has the value 100 it indicates that a protection function has operated during the fault if none of the protection functions has operated Start duration always shows values less than 100 The fault recorded data Protection rec set 1 or rec set 2 and Start duration are from the same protection function The fault recorded data operate time show...

Page 145: ... has twelve analog group inputs which must be properly configured All inputs can be connected to GRPOFF Table 84 Analog inputs Input Description I3P1 1 Three phase currents I3P2 1 Three phase currents I3P3 1 Three phase currents IRES1 1 Residual current measured or calculated IRES2 1 Residual current measured or calculated IRES3 1 Residual current measured or calculated U3P1 1 Three phase voltages...

Page 146: ...l three voltage channels are con nected to UTVTR Setting VT connection must be Wye in that particular UTVTR 3 9 4 Signals 3 9 4 1 FLTRFRC Input signals Table 86 FLTRFRC Input signals Name Type Default Description I3P1 SIGNAL Three phase currents 1 I3P2 SIGNAL Three phase currents 2 I3P3 SIGNAL Three phase currents 3 IRES1 SIGNAL Residual current 1 IRES2 SIGNAL Residual current 2 IRES3 SIGNAL Resid...

Page 147: ...urrent 3 9 6 Monitored data 3 9 6 1 FLTRFRC Monitored data Table 89 FLTRFRC Monitored data Name Type Values Range Unit Description Fault number INT32 0 999999 Fault record number Time and date Timestamp Fault record time stamp Protection rec set 1 Enum 0 None 1 PHLPTOC1 2 PHLPTOC2 6 PHHPTOC1 7 PHHPTOC2 8 PHHPTOC3 9 PHHPTOC4 12 PHIPTOC1 13 PHIPTOC2 17 EFLPTOC1 18 EFLPTOC2 19 EFLPTOC3 22 EFHPTOC1 23...

Page 148: ...SHDPFRQ4 69 LSHDPFRQ5 71 DPHLPDOC1 72 DPHLPDOC2 74 DPHHPDOC1 77 MAPGAPC1 78 MAPGAPC2 79 MAPGAPC3 85 MNSPTOC1 86 MNSPTOC2 88 LOFLPTUC1 90 TR2PTDF1 91 LNPLDF1 92 LREFPNDF1 94 MPDIF1 96 HREFPDIF1 100 ROVPTOV1 101 ROVPTOV2 102 ROVPTOV3 104 PHPTOV1 105 PHPTOV2 106 PHPTOV3 108 PHPTUV1 109 PHPTUV2 110 PHPTUV3 112 NSPTOV1 113 NSPTOV2 116 PSPTUV1 118 ARCSARC1 119 ARCSARC2 120 ARCSARC3 Table continues on th...

Page 149: ...PTOV1 15 PREVPTOC1 12 PHPTUC2 11 PHPTUC1 9 PHIZ1 5 PHLTPTOC1 20 EFLPTOC4 26 EFHPTOC5 27 EFHPTOC6 37 NSPTOC3 38 NSPTOC4 45 T1PTTR2 54 DEFHPDEF2 75 DPHHPDOC2 89 LOFLPTUC2 103 ROVPTOV4 117 PSPTUV2 13 PHPTUC3 3 PHLPTOC3 10 PHHPTOC5 11 PHHPTOC6 28 EFHPTOC7 29 EFHPTOC8 107 PHPTOV4 111 PHPTUV4 114 NSPTOV3 115 NSPTOV4 30 PHDSTPDIS1 29 TR3PTDF1 28 HICPDIF1 27 HIBPDIF1 26 HIAPDIF1 Table continues on the nex...

Page 150: ...46 FRPFRQ7 45 MAPGAPC24 44 MAPGAPC23 43 MAPGAPC22 42 MAPGAPC21 41 MAPGAPC20 40 MAPGAPC19 37 HAEFPTOC1 35 WPWDE3 34 WPWDE2 33 WPWDE1 52 DEFLPDEF3 84 MAPGAPC8 93 LREFPNDF2 97 HREFPDIF2 117 XDEFLPDEF2 116 XDEFLPDEF1 115 SDPHLPDOC2 114 SDPHLPDOC1 113 XNSPTOC2 112 XNSPTOC1 111 XEFIPTOC2 110 XEFHPTOC4 109 XEFHPTOC3 108 XEFLPTOC3 107 XEFLPTOC2 66 DQPTUV1 65 VVSPPAM1 64 PHPVOC1 63 H3EFPSEF1 60 HCUBPTOC1 T...

Page 151: ...6 LVRTPTUV3 122 DPH3LPDOC1 121 DPH3HPDOC2 120 DPH3HPDOC1 119 PH3LPTOC2 118 PH3LPTOC1 79 PH3HPTOC2 78 PH3HPTOC1 77 PH3IPTOC1 127 PHAPTUV1 124 PHAPTOV1 123 DPH3LPDOC2 68 PHPVOC2 67 DQPTUV2 39 UEXPDIS2 98 MHZPDIF1 4 MREFPTOC1 16 MPUPF1 14 OOSRPSB1 121 PSPTUV3 122 PSPTOV3 123 PHVPTOV1 39 DNSPDOC1 40 DNSPDOC2 126 PHCPTOV1 125 PHBPTOV1 97 HIAPDIF3 95 HICPDIF3 94 HICPDIF2 91 HIBPDIF3 90 HIBPDIF2 Table co...

Page 152: ...LOAT32 0 000 3 000 s Breaker clear time Fault distance FLOAT32 0 00 3000 00 pu Distance to fault meas ured in pu Fault resistance FLOAT32 0 00 3000 00 ohm Fault resistance Fault reactance FLOAT32 0 00 3000 00 ohm Fault reactance Active group INT32 1 6 Active setting group Shot pointer INT32 1 7 Autoreclosing shot pointer value Max diff current IL1 1 FLOAT32 0 000 80 000 pu Maximum phase A dif fere...

Page 153: ...dual current 1 Current Io Calc 1 FLOAT32 0 000 50 000 xIn Calculated residual cur rent 1 Current Ps Seq 1 FLOAT32 0 000 50 000 xIn Positive sequence cur rent 1 Current Ng Seq 1 FLOAT32 0 000 50 000 xIn Negative sequence cur rent 1 Max current IL1 2 FLOAT32 0 000 50 000 xIn Maximum phase A cur rent 2 Max current IL2 2 FLOAT32 0 000 50 000 xIn Maximum phase B cur rent 2 Max current IL3 2 FLOAT32 0 0...

Page 154: ... B voltage 2 Voltage UL3 2 FLOAT32 0 000 4 000 xUn Phase B voltage 2 Voltage U12 2 FLOAT32 0 000 4 000 xUn Phase A to phase B volt age 2 Voltage U23 2 FLOAT32 0 000 4 000 xUn Phase B to phase C volt age 2 Voltage U31 2 FLOAT32 0 000 4 000 xUn Phase C to phase A volt age 2 Voltage Uo 2 FLOAT32 0 000 4 000 xUn Residual voltage 2 Voltage Zro Seq 2 FLOAT32 0 000 4 000 xUn Zero sequence voltage 2 Volta...

Page 155: ...to phase B voltage 1 phase C current 1 Angle Uo 2 Io 2 FLOAT32 180 00 180 00 deg Angle residual voltage 2 residual current 2 Angle U23 2 IL1 2 FLOAT32 180 00 180 00 deg Angle phase B to phase C voltage 2 phase A current 2 Angle U31 2 IL2 2 FLOAT32 180 00 180 00 deg Angle phase C to phase A voltage 2 phase B current 2 Angle U12 2 IL3 2 FLOAT32 180 00 180 00 deg Angle phase A to phase B voltage 2 ph...

Page 156: ...ocal or 9 2 channels a certain number of numerical channels is always calculated from physical measurements This number also depends on the connection type of the TVTR function block Table 90 TVTR TCTR connection types and numerical channels Connection type Function block Physical channels Numerical channels ULx 1 ULxTVTR 1 0 URES ULxTVTR 1 0 ULx 2 Wye Delta ULxTVTR 2 4 ULx 2 URES Wye Delta ULxTVT...

Page 157: ...crease the measurement accuracy Correction factors are recommended to be set to the relay Two types of correction factors are available for voltage and current Rogowski sensors The Amplitude correction factor is named Amplitude corr A B C and Angle correction factor is named Angle corr A B C These correction factors can be found on the Sensor s rating plate and or sensor routine test protocol If t...

Page 158: ...n the protection relay s current Rogowski sensor settings can be set Table 92 Example setting values for current Rogowski sensor Setting Value Primary current 150 A Rated secondary value 5 625 mV Hz When considering setting values for current sensor interfaces and for protection functions utilizing these measurements it should be noted that the sensor measurement inputs in the relay have limits fo...

Page 159: ... relays using 80 A 0 150 V at 50 Hz Rogowski current sensors with rating plate values similar to Figure 56 For the incomer panel electrical system designer has evaluated the application nominal current to be 1250 A Customer specification for these protection relays defines normal instantaneous and time delayed overcurrent and earth fault protection functions Overcurrent protection requires functio...

Page 160: ...one common connection The binary inputs are bipolar so the common connection can be tied to ground or to supply voltage Input groups are isolated from each other and from the secondary side In addition there can be groups with only one input For more information see Chapter 13 1 Module diagrams in this manual In harsh industrial environments binary inputs are exposed to contamination This causes a...

Page 161: ...cific threshold 0 False 1 True 0 False Input threshold voltage 16 176 V 16 V 3 13 2 Threshold hysteresis Threshold hysteresis is used to determine the deactivation threshold for the binary inputs in case of voltage drops in the auxiliary voltage supply Threshold hysteresis value determines how low the deactivation voltage is compared to the activation voltage as a percentage Hysteresis can be set ...

Page 162: ...time parameter Input filter where is the number of the binary input of the module in question for example Input 1 filter Table 97 Input filter parameter values Parameter Values Default Input filter time 5 1000 ms 5 ms 3 13 4 Binary input inversion The parameter Input invert is used to invert a binary input Table 98 Binary input states Control voltage Input invert State of binary input No 0 FALSE 0...

Page 163: ... local or remote control actions of a breaker or a disconnector and for connecting the protection relay to external annunciation equipment for indicating signalling and recording Power output contacts are used when the current rating requirements of the contacts are high for example for controlling a breaker such as energizing the breaker trip and closing coils The contacts used for external signa...

Page 164: ...9 Dual single pole power outputs in power supply module 3 14 1 2 Double pole power outputs PODP1 PODP2 and PODP3 with trip circuit supervision The power outputs PODP1 PODP2 and PODP3 are double pole normally open form A power outputs with trip circuit supervision The trip circuit supervision hardware includes constant current generator to provide trip circuit supervision TCS current and TCS input ...

Page 165: ... a larger area With the static power outputs the total time from the application to the relay output contact activation is 4 6 ms shorter than when using output contacts with conventional mechanical output relays SPO5 and SPO7 are equipped with constant current generator to provide trip circuit supervision TCS current SPO6 and SPO8 are equipped with TCS input that can be connected to the TCS funct...

Page 166: ...l contact is rated for a continuous current of 5 A It has a make and carry for 0 5 seconds at 15 A When two contacts are connected in parallel the relay is of a different design It has the make and carry rating of 30 A for 0 5 seconds This can be applied for energizing breaker close coil and tripping coil Due to the limited breaking capacity a breaker auxiliary contact can be required to break the...

Page 167: ...Figure 62 Signal outputs in power supply module 1MRS759142 F Basic functions REX640 Technical Manual 167 ...

Page 168: ...odules 3 14 2 1 Internal fault signal output IRF The internal fault signal output change over form C IRF is a single contact included in the power supply module of the protection relay in slot G Basic functions 1MRS759142 F 168 REX640 Technical Manual ...

Page 169: ... The function is split into separate function blocks for each hardware channel The mA function block works as an interface for the mA current channel The channel can be defined either as a measuring input or a controllable output The RTD function block works as an interface for the RTD measuring channel that supports various types of RTD sensors Both function blocks have limit supervision alarm ou...

Page 170: ...Output 2 mode is activated with setting 20 20mA the Input 2 mode is blocked When a channel is configured as an output the alarm outputs are deactivated RTD modules RTD channels are used for resistance measurements and they are only input channels The inputs are configured for a particular input signal type by using the channel specific Input mode setting The default mode for each channel is Not in...

Page 171: ...to degrees Celsius The expected input range is 40 200 C However the output can be scaled to a narrower output range by setting Value mini mum and Value maximum Pt 250 Ni 100 Ni 120 Ni 250 Selection of value unit format Each input has an independent Value unit setting that is used to select the unit for the channel value representation The default value for the Value unit setting is Dimensionless T...

Page 172: ...197 83 30 88 22 220 56 84 15 100 97 210 36 20 92 16 230 40 89 30 107 16 223 24 10 96 09 240 21 94 58 113 50 236 45 0 100 00 250 00 100 00 120 00 250 00 10 103 90 259 76 105 55 126 66 263 88 20 107 79 269 48 111 24 133 48 278 09 30 111 67 279 18 117 06 140 47 292 64 40 115 54 288 85 123 01 147 61 307 53 50 119 40 298 49 129 11 154 93 322 76 60 123 24 308 10 135 34 162 41 338 35 70 127 08 317 69 141...

Page 173: ...t is not within 5 of the expected current the measurement is considered to be invalid and the channel is discarded until a valid current is obtained The expected currents are 1 mA for RTD sensors and 0 21 mA for pure resistance While the quality of the invalid input is set accordingly a warning is also provided on the Relay Status page of LHMI WHMI The invalid signal is deactivated as soon as the ...

Page 174: ...lue maximum 3 15 4 Application The general function block can be used in REX640 relays that are equipped with an RTD analog module The function can be applied to various applications for example to measure temperature pressure or flow 3 15 4 1 Input scaling Each mA RTD input can be scaled linearly by constructing a separate scaling curve for each input The curve consists of two points where the x ...

Page 175: ...6 36 20 mA Input AI_VAL Input minimum Input maximum Figure 70 Tap changer position from mA input Scaling example 3 When Input mode is set to Resistance the output can be scaled as desired For example the desired function output is a ratio in a function of resistance If the input resistance varies between 100 1600 ohms Input minimum is set to 100 and Input maximum is set to 1600 As the wanted outpu...

Page 176: ...ed values are compared against their set value limits The limit supervision outputs are HIGH_ALARM HIGH_WARN LOW_WARN and LOW_ALARM When an output is scaled Value maximum and Value minimum are the range limits to which the output value is limited or scaled Hysteresis is added to the range limit values so that the output value is allowed to slightly exceed or go below the limit value before being t...

Page 177: ...f Range Figure 72 Limit value supervision 3 15 4 3 Deadband supervision This is the same functionality as in measurement functions 3 15 4 4 Output scaling The mA outputs are scaled linearly by constructing linear scaling curves for each output Value maximum and Value minimum affect the scaled output range The range of the scaled input is defined with the settings Input minimum and Input maximum De...

Page 178: ...imum value is set to 24 kV and Input minimum value is set to 18 kV The input unit is not significant as long as the value range is in the same scale Value maximum is set to 20 mA and Value minimum to 4 mA Num of knee points is set to 0 Value minimum Value maximum 20 4 AO_VAL Output mA Input minimum 24 18 12 Input maximum 21 Figure 74 Scaling of AO_VAL to mA output Example 2 mA input to mA output S...

Page 179: ...ng of AO_VAL to mA output with two knee points Example 3 RTD input to mA output Slot mA1 AO_VAL AI_VAL HIGH_ALARM HIGH_WARN LOW_WARN LOW_ALARM Slot RTD 7 AI_VAL HIGH_ALARM HIGH_WARN LOW_WARN LOW_ALARM SENSOR_FLT Figure 77 Application example for RTD input to mA output Tap position is measured by the RTD channel 7 AI_VAL from channel 7 is connected to AO_VAL of channel 1 Input maximum is set to 160...

Page 180: ...re connection it is important that all three wires connecting the sensor are symmetrical that is the wires are of the same type and length Thus the wire resistance is automatically compensated RTD mA card variants The available variants of RTD cards are 10RTD 2mA and 3RTD 6mA The features are similar in both cards 10RTD 2mA card This card accepts two milliampere inputs and ten inputs from the RTD ...

Page 181: ...Figure 79 Four RTD resistance sensors connected according to the 3 wire connection for 10RTD 2mA card 1MRS759142 F Basic functions REX640 Technical Manual 181 ...

Page 182: ...Figure 80 Four RTD resistance sensors connected according to the 2 wire connection for 10RTD 2mA card Figure 81 mA channels working as mA inputs Basic functions 1MRS759142 F 182 REX640 Technical Manual ...

Page 183: ...Figure 82 mA channels working as mA outputs Figure 83 mA channels working as mA inputs 1MRS759142 F Basic functions REX640 Technical Manual 183 ...

Page 184: ...Figure 84 mA channels working as mA outputs Basic functions 1MRS759142 F 184 REX640 Technical Manual ...

Page 185: ...7 18 Ref RTD3 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Ref RTD1 Ref RTD2 mA mA2 mA mA3 mA mA4 mA mA5 mA mA6 13 14 15 BI3 BI2 BI1 BI4 BI7 BI6 BI5 BI8 BI11 BI10 BI9 BI12 Figure 85 RTD1002 module 1MRS759142 F Basic functions REX640 Technical Manual 185 ...

Page 186: ...ter Values Range Unit Step Default Description Input mode 1 Not in use 5 0 20mA 1 Not in use Analogue input mode Input maximum 20 20 mA Maximum analogue input value for mA or resistance scaling Input minimum 20 20 mA Minimum analogue input value for mA or resistance scaling Value unit 1 Dimensionless 5 Ampere 23 Degrees celsius 30 Ohm 1 Dimensionless Selected unit for output value format Value max...

Page 187: ...re 23 Degrees celsius 30 Ohm 1 Dimensionless Selected unit for output value format Value maximum 10000 0 10000 0 10000 Maximum output value for scal ing and supervision Value minimum 10000 0 10000 0 10000 Minimum output value for scal ing and supervision Val high high limit 10000 0 10000 0 10000 Output value high alarm limit for supervision Value high limit 10000 0 10000 0 10000 Output value high ...

Page 188: ...e knee point 3 20 0 20 0 mA 0 Knee point value 3 for output scaling Value knee point 2 20 0 20 0 mA 0 Knee point value 2 for output scaling Value knee point 1 20 0 20 0 mA 0 Knee point value 1 for output scaling Value minimum 20 0 20 0 mA 20 Minimum analog output value for mA output 3 15 8 Monitored data Table 113 mA Monitored data IEC name Type Values Range Unit Description AI_RANGE Enum mA input...

Page 189: ...ol block and the related data set into from the sending device s configuration It has only input signals SMVSENDER can be disabled with the Operation setting value off Toggling SMVSENDER on or off can be done from the LHMI When disabled the sending of the sample values is disabled 3 16 1 3 Settings Table 115 SMVSENDER Settings Parameter Values Range Unit Step Default Description Operation 1 on 5 o...

Page 190: ...Table 116 SMVRCV Output signals Name Type Description UL1 INT32 UL1 IEC61850 9 2 phase 1 voltage UL2 INT32 UL2 IEC61850 9 2 phase 2 voltage UL3 INT32 UL3 IEC61850 9 2 phase 3 voltage U0 INT32 Uo IEC61850 9 2 residual voltage IL1 INT32 IL1 IEC61850 9 2 phase 1 current IL2 INT32 IL2 IEC61850 9 2 phase 2 current IL3 INT32 IL3 IEC61850 9 2 phase 3 current I0 INT32 I0 IEC61850 9 2 residual current Basi...

Page 191: ...tting Current input type to Current trafo for conventional CT or to Current sensor for current sensor type The sensor s or the CT s primary rated current can be set using Primary current setting The setting Secondary current defines the nominal current of the CT s secondary winding This is used as a reference to scale the measurements accordingly These settings also affect the scaling of the calcu...

Page 192: ...three phase current can be activated with the setting Frequency adaptivity Three selections are provided Table 117 Frequency adaptivity setting for three phase current measurement Setting value Description Disable Frequency adaptive measurements are disabled for this ILTCTR Measurements are fixed to nominal frequency de fined with Configuration System Rated frequency Enable Frequency adaptive meas...

Page 193: ...Range Unit Step Default Description Current input type 2 Current trafo 4 Current sensor 2 Current trafo Type of the current input Primary current 1 0 15000 0 A 0 1 100 0 Rated primary cur rent Secondary current 2 1A 3 5A 2 1A Rated secondary current Rated secondary Val 1 000 150 000 mV Hz 0 001 3 000 Rated Secondary Value RSV ratio Amplitude Corr A 0 9000 1 1000 0 0001 1 0000 Phase A amplitude cor...

Page 194: ...CTR RESTCTR RESTCTR 3 17 2 2 Function block Figure 89 Function block 3 17 2 3 Functionality The residual current preprocessing function RESTCTR is used for setting up the residual current measurement channels Input channels for RESTCTR are either physical hardware or IEC 61850 9 2 sampled value channels The output IRES_MEAS channel of RESTCTR can be connected to different applications which requir...

Page 195: ...is negligible the WARNING or ALARM outputs are not activated The SMV Max Delay setting defines how long the receiver waits for the SMV frames before activating the ALARM output This setting can be accessed via Configuration System Waiting for the SMV frames also delays the local measurements of the receiver to keep them correctly time aligned The SMV Max Delay values include sampling processing an...

Page 196: ...A 3 5A 2 1A Secondary current Rated secondary Val 1 000 150 000 mV Hz 0 001 3 000 Rated Secondary Value RSV ratio Amplitude Corr 0 9000 1 1000 0 0001 1 0000 Amplitude correc tion Angle correction 8 0000 8 0000 deg 0 0001 0 0000 Angle correction factor Table 126 RESTCTR Non group settings Advanced Parameter Values Range Unit Step Default Description Reverse polarity 0 False 1 True 0 False Reverse t...

Page 197: ... and URES_CLC can be connected to different applications which require measured residual voltage or calculated residual voltage from phase voltages respectively If only two phase to earth phase to phase voltages are available then the third phase to earth phase to phase voltage can be calculated without URES input connected assumed to be zero in that case Positive and negative sequence components ...

Page 198: ...idual VT The VT connection can be set using VT connection For three phase to earth voltage measurements VT connection can be set to Wye and for three phase to phase voltage measurements VT connection can be set to Delta The MINCB_OPEN input signal is connected through a relay binary input to the NC auxiliary contact of the MCB protecting the VT secondary circuit The MINCB_OPEN signal receives info...

Page 199: ...s preprocessing block Backup frequency source Frequency adaptive measurements are enabled If the main frequency source cannot determine the network frequency the voltages of this preprocessing block determine the net work frequency All three phases must to be connected if the main or backup frequency source is selected Frequency adaptive measurements for residual voltage can be activated with the ...

Page 200: ... _URES_MEAS Figure 91 UTVTR1 configured with both measured and calculated U0 The VT connection mode must be WYE In this case ROVPTOV1 and ROVPTOV2 in Figure 92 can both use the same U0 reference level in their settings URES_CLC and URES_MEAS in Figure 91 are scaled to the same level ROVPTOV1 O 12 T 5 I 1 URES BLOCK OPERATE START ROVPTOV2 O 13 T 5 I 2 URES BLOCK OPERATE START UTVTR1 1 _URES_CLC UTV...

Page 201: ...current for disturbance recorder PPS_DR SIGNAL Positive sequence current for disturbance recorder FREQ_DR SIGNAL Measured frequency for dis turbance recorder 3 17 3 6 UTVTR Settings Table 131 UTVTR Non group settings Basic Parameter Values Range Unit Step Default Description Voltage input type 1 Voltage trafo 3 Voltage sensor 1 Voltage trafo Type of the voltage input Primary voltage 0 100 800 000 ...

Page 202: ...gle cor rection of an exter nal voltage trans former Table 132 UTVTR Non group settings Advanced Parameter Values Range Unit Step Default Description Frequency adaptivi ty 0 Disable 1 Enable 2 Main frequency source 3 Backup frequen cy source 0 Disable Frequency adaptivi ty selection Table 133 UTVTR Non group settings Basic Parameter Values Range Unit Step Default Description Primary voltage 0 100 ...

Page 203: ...ent measurement The residual primary rated current can be set using Primary current setting The setting Secondary voltage defines the nominal voltage of the measuring arrangement This is used as a reference to scale the measurements accordingly Residual current magnitude correction of an external measuring arrangement can be made using Amplitude Corr setting Residual current angle correction of an...

Page 204: ... correction 8 0000 8 0000 deg 0 0001 0 0000 Angle correction factor Table 138 RESUTCTR Non group settings Advanced Parameter Values Range Unit Step Default Description Reverse polarity 0 False 1 True 0 False Reverse the polari ty of the residual measurement Frequency adaptivi ty 0 Disable 1 Enable 0 Disable Frequency adaptivi ty selection 3 18 GOOSE function blocks GOOSE function blocks are used f...

Page 205: ...d GOOSE value for the application Default value 0 is used if VALID output indicates invalid status The IN input is defined in the GOOSE configuration and can always be seen in SMT sheet Settings The GOOSE function blocks do not have any parameters available in LHMI or PCM600 1MRS759142 F Basic functions REX640 Technical Manual 205 ...

Page 206: ... function GOOSERCV_BIN is used to connect the GOOSE binary inputs to the application 3 18 1 3 Signals Table 139 GOOSERCV_BIN Input signals Name Type Default Description IN BOOLEAN 0 Input signal Table 140 GOOSERCV_BIN Output signals Name Type Description OUT BOOLEAN Output signal VALID BOOLEAN Output signal Basic functions 1MRS759142 F 206 REX640 Technical Manual ...

Page 207: ...mation function GOOSERCV_DP is used to connect the GOOSE double binary inputs to the application 3 18 2 3 Signals Table 141 GOOSERCV_DP Input signals Name Type Default Description IN Dbpos 00 Input signal Table 142 GOOSERCV_DP Output signals Name Type Description OUT Dbpos Output signal VALID BOOLEAN Output signal 1MRS759142 F Basic functions REX640 Technical Manual 207 ...

Page 208: ...ation function GOOSERCV_MV is used to connect the GOOSE measured value inputs to the application 3 18 3 3 Signals Table 143 GOOSERCV_MV Input signals Name Type Default Description IN FLOAT32 0 Input signal Table 144 GOOSERCV_MV Output signals Name Type Description OUT FLOAT32 Output signal VALID BOOLEAN Output signal Basic functions 1MRS759142 F 208 REX640 Technical Manual ...

Page 209: ...information function GOOSERCV_INT8 is used to connect the GOOSE 8 bit integer inputs to the application 3 18 4 3 Signals Table 145 GOOSERCV_INT8 Input signals Name Type Default Description IN INT8 0 Input signal Table 146 GOOSERCV_INT8 Output signals Name Type Description OUT INT8 Output signal VALID BOOLEAN Output signal 1MRS759142 F Basic functions REX640 Technical Manual 209 ...

Page 210: ... information function GOOSERCV_INT32 is used to connect GOOSE 32 bit integer inputs to the application 3 18 5 3 Signals Table 147 GOOSERCV_INT32 Input signals Name Type Default Description IN INT32 0 Input signal Table 148 GOOSERCV_INT32 Output signals Name Type Description OUT INT32 Output signal VALID BOOLEAN Output signal Basic functions 1MRS759142 F 210 REX640 Technical Manual ...

Page 211: ...id status The CL output signal indicates that the position is closed Default value 0 is used if VALID output indicates invalid status The OK output signal indicates that the position is neither in faulty or intermediate state The default value 0 is used if VALID output indicates invalid status 3 18 6 3 Signals Table 149 GOOSERCV_INTL Input signals Name Type Default Description IN Dbpos 0 Input sig...

Page 212: ...ts are defined in the GOOSE configuration PCM600 The MAG output passes the received GOOSE amplitude and ANG the received angle value for the application 3 18 7 3 Signals Table 151 GOOSERCV_CMV Input signals Name Type Default Description MAG_IN FLOAT32 0 Input signal ampli tude ANG_IN FLOAT32 0 Input signal angle Table 152 GOOSERCV_CMV Output signals Name Type Description MAG FLOAT32 Output signal ...

Page 213: ...enumerator inputs to the application 3 18 8 3 Signals Table 153 GOOSERCV_ENUM Input signals Name Type Default Description IN Enum 0 Input signal Table 154 GOOSERCV_ENUM Output signals Name Type Description OUT Enum Output signal VALID BOOLEAN Output signal 3 19 Type conversion function blocks 3 19 1 Good signal quality QTY_GOOD 3 19 1 1 Function block Figure 102 Function block 1MRS759142 F Basic f...

Page 214: ...ame Type Default Description IN Any 0 Input signal Table 156 QTY_GOOD Output signals Name Type Description OUT BOOLEAN Output signal 3 19 2 Bad signal quality QTY_BAD 3 19 2 1 Function block Figure 103 Function block 3 19 2 2 Functionality The bad signal quality function QTY_BAD evaluates the quality bits of the input signal and passes it as a Boolean signal for the application The IN input can be...

Page 215: ...de differ in both editions 1 and 2 of the IEC 61850 standard For more information see the IEC 61850 engineering guide The IN input can be connected to any GOOSE application logic output signal for example GOOSERCV_BIN The OUT output indicates the test mode status of the GOOSE function block When the output is in the true 1 state the GOOSE test mode is active The value false 0 indicates that the te...

Page 216: ...tput signal for example GOOSERCV_BIN The COMMVALID output indicates the communication status of the GOOSE function block When the output is in the true 1 state the GOOSE communication is active The value false 0 indicates communication timeout 3 19 4 3 Signals Table 161 QTY_GOOSE_COMM Input signals Name Type Default Description IN Any 0 Input signal Table 162 QTY_GOOSE_COMM Output signals Name Typ...

Page 217: ...enumerated input value Only one of the outputs can be active at a time In case the GOOSERCV_ENUM function block does not receive the value from the sending device or it is invalid the default value 0 is used and the ALARM is activated in the T_HEALTH function block 3 19 5 3 Signals Table 163 T_HEALTH Input signals Name Type Default Description IN1 Any 0 Input signal Table 164 T_HEALTH Output signa...

Page 218: ...R and DIRECTION data attributes of the directional functions The outputs FWD and REV are extracted from the enumerated input value 3 19 6 3 Signals Table 165 T_DIR Input signals Name Type Default Description DIR Enum 0 Input signal Table 166 T_DIR Output signals Name Type Description FWD BOOLEAN Direction forward REV BOOLEAN Direction backward Basic functions 1MRS759142 F 218 REX640 Technical Manu...

Page 219: ...data of the FAULT_DIR and DIRECTION data attributes of the directional functions The output FWD is extracted from the enumerated input value 3 19 7 3 Signals Table 167 T_DIR_FWD Input signals Name Type Default Description DIR Enum 0 Input signal Table 168 T_DIR_FWD Output signals Name Type Description FWD BOOLEAN Direction forward 1MRS759142 F Basic functions REX640 Technical Manual 219 ...

Page 220: ...data of the FAULT_DIR and DIRECTION data attributes of the directional functions The output REV is extracted from the enumerated input value 3 19 8 3 Signals Table 169 T_DIR_REV Input signals Name Type Default Description DIR Enum 0 Input signal Table 170 T_DIR_REV Output signals Name Type Description REV BOOLEAN Direction backward Basic functions 1MRS759142 F 220 REX640 Technical Manual ...

Page 221: ...als to boolean output signals Table 171 Conversion from enumerated to Boolean IN RAISE LOWER 0 FALSE FALSE 1 FALSE TRUE 2 TRUE FALSE x FALSE FALSE 3 19 9 3 Signals Table 172 T_TCMD input signals Name Type Default Description IN Enum 0 Input signal Table 173 T_TCMD output signals Name Type Description RAISE BOOLEAN Raise command LOWER BOOLEAN Lower command 1MRS759142 F Basic functions REX640 Techni...

Page 222: ...teger input signal to boolean output signals Table 174 Conversion from integer to Boolean IN RAISE LOWER 0 FALSE FALSE 1 FALSE TRUE 2 TRUE FALSE x FALSE FALSE 3 19 10 3 Signals Table 175 T_TCMD_BIN input signals Name Type Default Description IN INT32 0 Input signal Table 176 T_TCMD_BIN output signals Name Type Description RAISE BOOLEAN Raise command LOWER BOOLEAN Lower command Basic functions 1MRS...

Page 223: ...an input signals to 32 bit integer output signals Table 177 Conversion from Boolean to integer RAISE LOWER OUT FALSE FALSE 0 FALSE TRUE 1 TRUE FALSE 2 3 19 11 3 Signals Table 178 T_BIN_TCMD input signals Name Type Default Description RAISE BOOLEAN 0 Raise command LOWER BOOLEAN 0 Lower command Table 179 T_BIN_TCMD output signals Name Type Description OUT INT32 Output signal 1MRS759142 F Basic funct...

Page 224: ...eger value is greater than 2097151 then the real value is set to 2097151 and the output quality is set as bad If the integer value is less than 2097152 then the real value is set to 2097152 and the output quality is set as bad 3 19 12 3 Signals Table 180 T_I32_TO_R Input signals Name Type Default Description INT32_IN INT32 0 Integer input value Table 181 T_I32_TO_R Output signals Name Type Descrip...

Page 225: ... integer value The output quality follows the input quality information If the real value is 10 6 10 5 10 4 10 6 10 5 10 4 the integer value is converted to 10 10 10 11 11 11 respectively 3 19 13 3 Signals Table 182 T_R_TO_I8 Input signals Name Type Default Description REAL_IN FLOAT32 0 Real input value Table 183 T_R_TO_I8 Output signals Name Type Description INT8_OUT INT8 Integer output value 1MR...

Page 226: ...o integer value The output quality follows the input quality information If the real value is 10 6 10 5 10 4 10 6 10 5 10 4 the integer value is converted to 10 10 10 11 11 11 respectively 3 19 14 3 Signals Table 184 T_R_TO_I32 Input signals Name Type Default Description REAL_IN FLOAT32 0 Real input value Table 185 T_R_TO_I32 Output signals Name Type Description INT32_OUT INT32 Integer output valu...

Page 227: ...n the INT32_IN1 and INT32_IN2 inputs Table 186 SWITCHI32 CTL_SW value INT_OUT value FALSE 0 INT32_IN1 TRUE 1 INT32_IN2 3 19 15 3 Signals Table 187 SWITCHI32 Input signals Name Type Default Description CTL_SW BOOLEAN 0 Control Switch INT_IN1 INT32 0 Integer input value 1 INT_IN2 INT32 0 Integer input value 2 Table 188 SWITCHI32 Output signals Name Type Description INT_OUT INT32 Integer switch outpu...

Page 228: ...16 1 the higher bits are ignored in conversion 3 19 16 3 Signals Table 189 T_I32_TO_B16 Input signals Name Type Default Description INT32_IN INT32 0 Integer input value Table 190 T_I32_TO_B16 Output signals Name Type Description OUT1 BOOLEAN Boolean output value 1 OUT2 BOOLEAN Boolean output value 2 OUT3 BOOLEAN Boolean output value 3 OUT4 BOOLEAN Boolean output value 4 OUT5 BOOLEAN Boolean output...

Page 229: ...n to integer 32 bit conversion function T_B16_TO_I32 is used to transform a set of 16 binary logical signals IN1 IN16 into an integer 32 bit output INT32_OUT value 3 19 17 3 Signals Table 191 T_B16_TO_I32 Input signals Name Type Default Description IN1 BOOLEAN 0 FALSE Boolean input value 1 IN2 BOOLEAN 0 FALSE Boolean input value 2 IN3 BOOLEAN 0 FALSE Boolean input value 3 IN4 BOOLEAN 0 FALSE Boole...

Page 230: ... input value 16 Table 192 T_B16_TO_I32 Output signals Name Type Description INT32_OUT INT32 Integer output value 3 19 18 Integer 8 bit to integer 32 bit conversion T_I8_TO_I32 3 19 18 1 Function block Figure 119 Function block 3 19 18 2 Functionality The integer 8 bit to integer 32 bit conversion function T_I8_TO_I32 converts a 8 bit integer value to a 32 bit integer value The output quality follo...

Page 231: ...ion block Figure 120 Function block Functionality The minimum pulse timer two channels function TPGAPC contains two independent timers The function has a settable pulse length in milliseconds The timers are used for setting the minimum pulse length for example the signal outputs Once the input is activated the output is set for a specific duration using the Pulse time setting Both timers use the s...

Page 232: ...cation Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Minimum pulse timer second reso lution two channels TPSGAPC TPS 62TPS Function block Figure 122 Function block Functionality The minimum pulse timer second resolution two channels function TPSGAPC contains two independent timers The function has a settable pulse length in seconds The timers ...

Page 233: ...on IN1 BOOLEAN 0 False Input 1 IN2 BOOLEAN 0 False Input 2 Table 199 TPSGAPC Output signals Name Type Description OUT1 BOOLEAN Output 1 status OUT2 BOOLEAN Output 2 status Settings Table 200 TPSGAPC Non group settings Basic Parameter Values Range Unit Step Default Description Pulse time 0 300 s 1 0 Minimum pulse time 1MRS759142 F Basic functions REX640 Technical Manual 233 ...

Page 234: ... pulse length in minutes The timers are used for setting the minimum pulse length for example the signal outputs Once the input is activated the output is set for a specific duration using the Pulse time setting Both timers use the same setting parameter Figure 125 A Trip pulse is shorter than Pulse time setting B Trip pulse is longer than Pulse time setting Signals Table 201 TPMGAPC Input signals...

Page 235: ...imer eight channels PTGAPC ANSI 62PT 3 20 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Pulse timer eight channels PTGAPC PT 62PT 3 20 2 2 Function block Figure 126 Function block 3 20 2 3 Functionality The pulse timer function PTGAPC contains eight independent timers The function has a settable pulse length Once the input i...

Page 236: ...Description Q1 BOOLEAN Output 1 status Q2 BOOLEAN Output 2 status Q3 BOOLEAN Output 3 status Q4 BOOLEAN Output 4 status Q5 BOOLEAN Output 5 status Q6 BOOLEAN Output 6 status Q7 BOOLEAN Output 7 status Q8 BOOLEAN Output 8 status 3 20 2 5 Settings Table 207 PTGAPC Non group settings Basic Parameter Values Range Unit Step Default Description Pulse time 1 0 3600000 ms 1 0 Pulse time Pulse time 2 0 360...

Page 237: ... s Time left 6 T_LEFT7 FLOAT32 0 3600 s Time left 7 T_LEFT8 FLOAT32 0 3600 s Time left 8 3 20 2 7 Technical data Table 209 PTGAPC Technical data Characteristic Value Operate time accuracy 1 0 of the set value or 20 ms 3 20 2 8 Technical revision history Table 210 PTGAPC Technical revision history Product connectivity level Technical revision Change PCL2 E Changed the Pulse time step to 1 ms 3 20 3...

Page 238: ...y When the time of the day reaches the set activation time output Q is activated and remains active for the duration defined by the setting xxx off delay The output remains active until the next day if the value for xxx off delay is set so that it results into rollover of the day Different activation and deactivation times can be set for all days of the week The activation and deactivation can als...

Page 239: ...20 3 6 Signals DTMGAPC Input signals Table 211 DTMGAPC Input signals Name Type Default Description BLOCK BOOLEAN 0 False Block signal for bina ry output FREEZE BOOLEAN 0 False Freeze signal for bina ry output DTMGAPC Output signals Table 212 DTMGAPC Output signals Name Type Description Q BOOLEAN Output status 3 20 3 7 DTMGAPC Settings Table 213 DTMGAPC Non group settings Basic Parameter Values Ran...

Page 240: ...vation hour time for Thursday Thursday Act Mn 0 59 min 0 Activation minute time for Thursday Thursday off delay 1 1440 min 1 60 Activation duration for Thursday Friday Act enable 0 False 1 True false Activation deacti vation need on Fri day Friday Act hour 0 23 h 8 Activation hour time for Friday Friday Act Mn 0 59 min 0 Activation minute time for Friday Friday off delay 1 1440 min 1 60 Activation...

Page 241: ...te a function output at a set activation date of the calendar year The output remains activated till the set deactivation date of the calendar year 3 20 4 4 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are on and off The operation of CALGAPC can be described with a module diagram Q Date comparator BLOCK FREEZE Figure 132...

Page 242: ...1st April then the last date of the month is considered Q 5 12 10 12 20 12 15 12 31 12 25 12 Set Activation day 07 Activation month December Set Deactivation day 22 Deactivation month December 7 12 22 12 Q 20 12 25 12 5 1 31 12 15 1 10 1 Set Activation day 22 Activation month December Set Deactivation day 07 Deactivation month January 22 12 7 1 Figure 133 Examples of how output Q is activated for ...

Page 243: ...settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Activation day 1 31 1 Activation day Activation month 1 January 2 February 3 March 4 April 5 May 6 June 7 July 8 August 9 September 10 October 11 November 12 December 1 January Activation month Deactivation day 1 31 31 Deactivation day Deactivation month 1 January 2 February 3 March 4 Apr...

Page 244: ... IEEE C37 2 device number Time delay off eight channels TOFGAPC TOF 62TOF 3 20 5 2 Function block Figure 135 Function block 3 20 5 3 Functionality The time delay off eight channels function TOFGAPC can be used for example for a drop off delayed output related to the input signal The function contains eight independent timers There is a settable delay in the timer Once the input is activated the ou...

Page 245: ... Description Q1 BOOLEAN Output 1 status Q2 BOOLEAN Output 2 status Q3 BOOLEAN Output 3 status Q4 BOOLEAN Output 4 status Q5 BOOLEAN Output 5 status Q6 BOOLEAN Output 6 status Q7 BOOLEAN Output 7 status Q8 BOOLEAN Output 8 status 3 20 5 5 Settings Table 221 TOFGAPC Non group settings Basic Parameter Values Range Unit Step Default Description Off delay time 1 0 3600000 ms 1 0 Off delay time Off dela...

Page 246: ...AT32 0 3600 s Time left 6 T_LEFT7 FLOAT32 0 3600 s Time left 7 T_LEFT8 FLOAT32 0 3600 s Time left 8 3 20 5 7 Technical data Table 223 TOFGAPC Technical data Characteristic Value Operate time accuracy 1 0 of the set value or 20 ms 3 20 5 8 Technical revision history Table 224 TOFGAPC Technical revision history Product connectivity level Technical revision Change PCL2 D Changed the Off delay time st...

Page 247: ...g has elapsed t0 t0 dt t2 t3 t4 dt dt On delay time t1 t4 t5 Figure 138 Timer operation 3 20 6 4 Signals Table 225 TONGAPC Input signals Name Type Default Description IN1 BOOLEAN 0 False Input 1 IN2 BOOLEAN 0 False Input 2 IN3 BOOLEAN 0 False Input 3 IN4 BOOLEAN 0 False Input 4 IN5 BOOLEAN 0 False Input 5 IN6 BOOLEAN 0 False Input 6 IN7 BOOLEAN 0 False Input 7 IN8 BOOLEAN 0 False Input 8 Table 226...

Page 248: ...6 0 3600000 ms 1 0 On delay time On delay time 7 0 3600000 ms 1 0 On delay time On delay time 8 0 3600000 ms 1 0 On delay time 3 20 6 6 Monitored data Table 228 TONGAPC Monitored data Name Type Values Range Unit Description T_LEFT1 FLOAT32 0 3600 s Time left 1 T_LEFT2 FLOAT32 0 3600 s Time left 2 T_LEFT3 FLOAT32 0 3600 s Time left 3 T_LEFT4 FLOAT32 0 3600 s Time left 4 T_LEFT5 FLOAT32 0 3600 s Tim...

Page 249: ...PC SR SR 3 20 7 2 Function block Figure 139 Function block 3 20 7 3 Functionality The SR flip flop eight channels nonvolatile function SRGAPC is a simple SR flip flop with a memory that can be set or that can reset an output from the S or R inputs respectively The function contains eight independent set reset flip flop latches where the SET input has the higher priority over the RESET input The st...

Page 250: ...R3 BOOLEAN 0 False Resets Q3 output when set S4 BOOLEAN 0 False Set Q4 output when set R4 BOOLEAN 0 False Resets Q4 output when set S5 BOOLEAN 0 False Set Q5 output when set R5 BOOLEAN 0 False Resets Q5 output when set S6 BOOLEAN 0 False Set Q6 output when set R6 BOOLEAN 0 False Resets Q6 output when set S7 BOOLEAN 0 False Set Q7 output when set R7 BOOLEAN 0 False Resets Q7 output when set S8 BOOL...

Page 251: ...when set Reset Q3 0 Cancel 1 Reset 0 Cancel Resets Q3 output when set Reset Q4 0 Cancel 1 Reset 0 Cancel Resets Q4 output when set Reset Q5 0 Cancel 1 Reset 0 Cancel Resets Q5 output when set Reset Q6 0 Cancel 1 Reset 0 Cancel Resets Q6 output when set Reset Q7 0 Cancel 1 Reset 0 Cancel Resets Q7 output when set Reset Q8 0 Cancel 1 Reset 0 Cancel Resets Q8 output when set 3 20 8 Boolean value even...

Page 252: ...tion IN1 BOOLEAN 0 False IN1 status IN2 BOOLEAN 0 False IN2 status IN3 BOOLEAN 0 False IN3 status IN4 BOOLEAN 0 False IN4 status IN5 BOOLEAN 0 False IN5 status IN6 BOOLEAN 0 False IN6 status IN7 BOOLEAN 0 False IN7 status IN8 BOOLEAN 0 False IN8 status Table 236 MVGAPC Output signals Name Type Description Q1 BOOLEAN Q1 status Q2 BOOLEAN Q2 status Q3 BOOLEAN Q3 status Q4 BOOLEAN Q4 status Q5 BOOLEA...

Page 253: ...50 identification IEC 60617 identification ANSI IEEE C37 2 device number Integer value event creation MVI4GAPC MVI4 MVI4 3 20 9 2 Function block Figure 141 Function block 3 20 9 3 Functionality The integer value event creation function MVI4GAPC is used for creation of the events from the integer values The integer input value is received via IN1 4 input The integer output value is available on OUT...

Page 254: ...SCA4GAPC SCA4 SCA4 3 20 10 2 Function block Figure 142 Function block 3 20 10 3 Functionality The analog value event creation with scaling function SCA4GAPC is used for scaling the analog value It allows creating events from analog values The analog value received via the AIn_VALUE input is scaled with the Scale ratio n setting The scaled value is available on the AOn_VALUE output Analog input ran...

Page 255: ...AT32 Analog value 2 after scaling AO3_VALUE FLOAT32 Analog value 3 after scaling AO4_VALUE FLOAT32 Analog value 4 after scaling 3 20 10 5 Settings Table 242 SCA4GAPC settings Parameter Values Range Unit Step Default Description Scale ratio 1 0 001 1000 000 0 001 1 000 Scale ratio for analog value 1 Scale ratio 2 0 001 1000 000 0 001 1 000 Scale ratio for analog value 2 Scale ratio 3 0 001 1000 000...

Page 256: ... Analog value 3 AO4_VALUE FLOAT32 Analog value 4 AO5_VALUE FLOAT32 Analog value 5 AO6_VALUE FLOAT32 Analog value 6 AO7_VALUE FLOAT32 Analog value 7 AO8_VALUE FLOAT32 Analog value 8 AO9_VALUE FLOAT32 Analog value 9 AO10_VALUE FLOAT32 Analog value 10 AO11_VALUE FLOAT32 Analog value 11 AO12_VALUE FLOAT32 Analog value 12 AO13_VALUE FLOAT32 Analog value 13 AO14_VALUE FLOAT32 Analog value 14 AO15_VALUE ...

Page 257: ... 9 2000000 000 200 0000 000 0 001 0 Set value for analog value 9 Set value 10 2000000 000 200 0000 000 0 001 0 Set value for analog value 10 Set value 11 2000000 000 200 0000 000 0 001 0 Set value for analog value 11 Set value 12 2000000 000 200 0000 000 0 001 0 Set value for analog value 12 Set value 13 2000000 000 200 0000 000 0 001 0 Set value for analog value 13 Set value 14 2000000 000 200 00...

Page 258: ... INT32 Integer value 3 IO4_VALUE INT32 Integer value 4 IO5_VALUE INT32 Integer value 5 IO6_VALUE INT32 Integer value 6 IO7_VALUE INT32 Integer value 7 IO8_VALUE INT32 Integer value 8 IO9_VALUE INT32 Integer value 9 IO10_VALUE INT32 Integer value 10 IO11_VALUE INT32 Integer value 11 IO12_VALUE INT32 Integer value 12 IO13_VALUE INT32 Integer value 13 IO14_VALUE INT32 Integer value 14 IO15_VALU INT32...

Page 259: ...alue 8 Set value 9 2147483648 2147 483647 1 0 Set value for integer value 9 Set value 10 2147483648 2147 483647 1 0 Set value for integer value 10 Set value 11 2147483648 2147 483647 1 0 Set value for integer value 11 Set value 12 2147483648 2147 483647 1 0 Set value for integer value 12 Set value 13 2147483648 2147 483647 1 0 Set value for integer value 13 Set value 14 2147483648 2147 483647 1 0 ...

Page 260: ...ed according to the R L button state Each of the 16 generic control point outputs has the Operation mode Pulse length and Description setting If Operation mode is Toggle the output state is toggled for every control request received If Operation mode is Pulsed the output pulse of a preset duration the Pulse length setting is generated for every control request received The Description setting can ...

Page 261: ... 1 IN2 BOOLEAN 0 False Input of control point 2 IN3 BOOLEAN 0 False Input of control point 3 IN4 BOOLEAN 0 False Input of control point 4 IN5 BOOLEAN 0 False Input of control point 5 IN6 BOOLEAN 0 False Input of control point 6 IN7 BOOLEAN 0 False Input of control point 7 IN8 BOOLEAN 0 False Input of control point 8 IN9 BOOLEAN 0 False Input of control point 9 IN10 BOOLEAN 0 False Input of control...

Page 262: ...ut 5 status O6 BOOLEAN Output 6 status O7 BOOLEAN Output 7 status O8 BOOLEAN Output 8 status O9 BOOLEAN Output 9 status O10 BOOLEAN Output 10 status O11 BOOLEAN Output 11 status O12 BOOLEAN Output 12 status O13 BOOLEAN Output 13 status O14 BOOLEAN Output 14 status O15 BOOLEAN Output 15 status O16 BOOLEAN Output 16 status Basic functions 1MRS759142 F 262 REX640 Technical Manual ...

Page 263: ...ration mode 0 Pulsed 1 Toggle Persistent 1 Off 1 Off Operation mode for generic con trol point Pulse length 10 3600000 ms 10 1000 Pulse length for pulsed operation mode Description SPCGAPC1 Output 4 Generic control point description Operation mode 0 Pulsed 1 Toggle Persistent 1 Off 1 Off Operation mode for generic con trol point Pulse length 10 3600000 ms 10 1000 Pulse length for pulsed operation ...

Page 264: ...ration mode 0 Pulsed 1 Toggle Persistent 1 Off 1 Off Operation mode for generic con trol point Pulse length 10 3600000 ms 10 1000 Pulse length for pulsed operation mode Description SPCGAPC1 Output 12 Generic control point description Operation mode 0 Pulsed 1 Toggle Persistent 1 Off 1 Off Operation mode for generic con trol point Pulse length 10 3600000 ms 10 1000 Pulse length for pulsed operation...

Page 265: ...l energy meter for the calculation of energy consumption values The pulses are captured by the binary input module and read by PCGAPC The number of pulses in the counter is then reported via the station bus to the automation system or read via the station monitoring system as a service value The scaled value is also available over IEC 61850 communication The pulses are captured by the binary input...

Page 266: ...communication protocols depending on the Reporting interval setting The start of Reporting interval corresponds to the start of the function operation in the protection relay Binary output VALUE_READ activates for a fixed 200 ms each time the reporting timer completes its cycle It is also possible to update COUNT_VALUE before completion of Reporting interval and make it available for communication...

Page 267: ...Reporting interval setting The start of Reporting interval corresponds to the start of the function operation in the protection relay The activation of RESET resets SCALED_VALUE to zero If Pulse quantity Impulse ratio or Impulse ratio prefix is changed in between SCALED_VALUE is updated immediately based on the new setting Binary output VALUE_READ activates for a fixed 200 ms each time the reporti...

Page 268: ...rting time VALUE_READ READ_VALUE SCALED_VALUE 30 40 50 8 9 90 RESET Reporting time 1 2 3 0 00 30 Unit selection set to Count Pulse quantity set to 10 Fixed pulse of 200ms COUNT_VALUE 3 3 0 5 4 9 Figure 149 PCGAPC operation Basic functions 1MRS759142 F 268 REX640 Technical Manual ...

Page 269: ...ernally generated binary pulses for example pulses coming from an external energy meter for the calculation of energy consumption values The pulses are captured by the binary input module and read by PCGAPC with a frequency of up to 40 Hz The number of pulses in the counter is then reported via the station bus to the substation automation system or read via the station monitoring system as a servi...

Page 270: ...le 251 PCGAPC Input signals Name Type Default Description PULSE_INPUT BOOLEAN 0 False Connect binary input channel for counting READ_VALUE BOOLEAN 0 False Initiates an additional pulse counter reading RESET BOOLEAN 0 False Resets pulse counter value FREEZE_COUNT BOOLEAN 0 False Freeze counting of pulse available at in put PCGAPC Output signals Table 252 PCGAPC Output signals Name Type Description ...

Page 271: ...Pulse quantity 0 0001 90000 000 0 0 0001 1 0000 Factor to be multiplied with COUNT_VALUE Reporting interval 0 1 minute 1 5 minutes 2 10 minutes 3 15 minutes 4 30 minutes 5 60 minutes 6 180 minutes 0 1 minute Reporting interval for counter value 3 20 14 8 PCGAPC Monitored data Table 254 PCGAPC Monitored data Name Type Values Range Unit Description COUNT_VALUE INT64 0 2147483647 da Actual pulse coun...

Page 272: ...changed from off to on the monitored variable TAG_SOURCE is set to None and saved to a nonvolatile memory When the Operation setting is on and a reboot occurs the TAG_SOURCE variable is read from the nonvolatile memory The operation of HLTGAPC can be described with a module diagram All the modules in the diagram are explained in the next sections TAG_ON_OFF TAG_OFF TAG_ON Local command TAG_SOURCE ...

Page 273: ...ly through the LHMI or remotely through a communications command In order to operate correctly HLTGAPC must be properly configured with Application Configuration The TAG_ON and TAG_OFF outputs are connected where they can block or enable any reclosing that is configured Typically TAG_ON can be used on a recloser function block to inhibit reclosing and TAG_OFF can be used on a circuit breaker funct...

Page 274: ...FF BOOLEAN Hotline tag is not active 3 20 15 7 HLTGAPC Settings Table 257 HLTGAPC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Remote tag mode 1 Untag Rem only 2 Untag Loc or Rem 1 Untag Rem only Deactivation mode for remotely set hotline tag 3 20 15 8 HLTGAPC Monitored data Table 258 HLTGAPC Monitored data Name Type Value...

Page 275: ...n can also be associated with the residual voltage if available The calculated components U U and U0 and the calculated P2P P2E depending of the wye delta mode are switch controlled as well 3 20 16 4 Analog channel configuration VMSWI has eight analog group inputs which must be properly configured All inputs can be connected to GRPOFF Table 259 Analog inputs Input Description U3P1 1 Three phase vo...

Page 276: ...4 calculated The function requires that all three voltage channels are con nected to calculate the residual voltage Setting VT connec tion must be Wye in that particular UTVTR 3 20 16 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are on and off For this function the setting is hidden and fixed to on The switch logic dep...

Page 277: ...ltaneously to the protection relay 3 20 16 6 Signals Table 262 VMSWI Input signals Name Type Default Description U3P1 SIGNAL Three phase voltages 1 U3P2 SIGNAL Three phase voltages 2 U3P3 SIGNAL Three phase voltages 3 U3P4 SIGNAL Three phase voltages 4 URES1 SIGNAL Residual voltage 1 URES2 SIGNAL Residual voltage 2 URES3 SIGNAL Residual voltage 3 URES4 SIGNAL Residual voltage 4 SWITCH_TO2 BOOLEAN ...

Page 278: ...7 2 Function block Figure 155 Function block 3 20 17 3 Functionality The current switch function CMSWI performs the switching function between up to four current groups Bus1 Bus 2 Bus 3 and Bus 4 The residual current input is optional and depends of the application configuration Switching operation can also be associated with the residual current if this is available 3 20 17 4 Analog channel confi...

Page 279: ...done on increased priority GRPOFF signal must be connected to unused current inputs GRPOFF signal is available as output from the Protection function block Table 266 Switching operation Control input signals Outputs SWITCH_TO 2 SWITCH_TO 3 SWITCH_TO 4 SOURCE1 SOURCE2 SOURCE3 SOURCE4 Source for I3P Source for IRES FALSE FALSE FALSE TRUE FALSE FALSE FALSE I3P1 IRES1 TRUE FALSE FALSE FALSE TRUE FALSE...

Page 280: ...GNAL Residual current 2 IRES3 SIGNAL Residual current 3 IRES4 SIGNAL Residual current 4 SWITCH_TO2 BOOLEAN 0 False Switch to source 2 SWITCH_TO3 BOOLEAN 0 False Switch to source 3 SWITCH_TO4 BOOLEAN 0 False Switch to source 4 Table 268 CMSWI Output signals Name Type Description SOURCE1 BOOLEAN Selected current source is source 1 SOURCE2 BOOLEAN Selected current source is source 2 SOURCE3 BOOLEAN S...

Page 281: ...corresponding inputs The counter value output can be reset to zero or preset to some other value if required The function provides up count and down count status outputs which specify the relation of the counter value to a loaded preset value and to zero respectively 3 20 18 4 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values...

Page 282: ...t to True when the CNT_VAL is greater than or equal to the setting Counter load value DNCNT_STS is set to True when the CNT_VAL is zero The RESET input is used for resetting the function When this input is set to True or when Reset counter is set to reset the CNT_VAL is forced to zero 3 20 18 5 Signals Table 270 UDFCNT Input signals Name Type Default Description UP_CNT BOOLEAN 0 False Input for up...

Page 283: ...2 device number Current sum CMSUM CSUM CSUM 3 20 19 2 Function block Figure 158 Function block 3 20 19 3 Functionality The current sum function CMSUM is a phase by phase specific summing function for two current triplets Output I3P can be used as normal current input for the application functions using current Different measurement modes DFT RMS Peak to peak are supported Also positive negative an...

Page 284: ...e the same primary current setting value Table 274 Analog inputs Input Description I3P1 Three phase currents I3P2 Three phase currents See the preprocessing function blocks in this document for the possible signal sources 3 20 19 5 Signals Table 275 CMSUM Input signals Name Type Default Description I3P1 SIGNAL Three phase currents 1 I3P2 SIGNAL Three phase currents 2 Basic functions 1MRS759142 F 2...

Page 285: ...ombiner OLGAPC OLGAPC OLGAPC 3 20 20 2 Function block Figure 160 Function block 3 20 20 3 Functionality The transformer data combiner function OLGAPC is intended for the voltage regulator function OL5ATCC 3 20 20 4 Operation principle The function of OLGAPC is to collect data from a parallel transformer via GOOSE communication The TR_DAT output which contains the combined input data is connected t...

Page 286: ...ng er position of trans former TR_I_AMPL FLOAT32 0 00 Received current magnitude from transformer TR_I_ANGL FLOAT32 0 00 Received current an gle from transformer TR_STATUS Enum 0 Independent Transformer status information OLGAPC Output signals Table 278 OLGAPC Output signals Name Type Description TR_DAT INT8_TRDAT Analog output Basic functions 1MRS759142 F 286 REX640 Technical Manual ...

Page 287: ...n the related setting Connect INx to Qx Additionally each output Qx can be named with Description setting 3 20 21 4 Signals Table 279 GATEGAPC Input signals Name Type Default Description IN1 BOOLEAN 0 IN1 status IN2 BOOLEAN 0 IN2 status IN3 BOOLEAN 0 IN3 status IN4 BOOLEAN 0 IN4 status IN5 BOOLEAN 0 IN5 status IN6 BOOLEAN 0 IN6 status IN7 BOOLEAN 0 IN7 status IN8 BOOLEAN 0 IN8 status Table 280 GAT...

Page 288: ... Q3 1 On 0 Off 0 Off IN3 to Q3 connection Description GATEGAPC1 Q3 Output description Connect IN4 to Q4 1 On 0 Off 0 Off IN4 to Q4 connection Description GATEGAPC1 Q4 Output description Connect IN5 to Q5 1 On 0 Off 0 Off IN5 to Q5 connection Description GATEGAPC1 Q5 Output description Connect IN6 to Q6 1 On 0 Off 0 Off IN6 to Q6 connection Description GATEGAPC1 Q6 Output description Connect IN7 to...

Page 289: ... variables The O output is activated when at least one input has the value TRUE The default value of all inputs is FALSE which makes it possible to use only the required number of inputs and leave the rest disconnected OR has two inputs OR6 six and OR20 twenty inputs 3 21 1 3 Signals Table 282 OR Input signals Name Type Default Description B1 BOOLEAN 0 Input signal 1 B2 BOOLEAN 0 Input signal 2 1M...

Page 290: ... 0 Input signal 6 B7 BOOLEAN 0 Input signal 7 B8 BOOLEAN 0 Input signal 8 B9 BOOLEAN 0 Input signal 9 B10 BOOLEAN 0 Input signal 10 B11 BOOLEAN 0 Input signal 11 B12 BOOLEAN 0 Input signal 12 B13 BOOLEAN 0 Input signal 13 B14 BOOLEAN 0 Input signal 14 B15 BOOLEAN 0 Input signal 15 B16 BOOLEAN 0 Input signal 16 B17 BOOLEAN 0 Input signal 17 B18 BOOLEAN 0 Input signal 18 B19 BOOLEAN 0 Input signal 1...

Page 291: ...2 Functionality AND AND6 and AND20 are used to form general combinatory expressions with boolean variables The default value in all inputs is logical TRUE which makes it possible to use only the required number of inputs and leave the rest disconnected AND has two inputs AND6 six inputs and AND20 twenty inputs 3 21 2 3 Signals Table 288 AND Input signals Name Type Default Description B1 BOOLEAN 1 ...

Page 292: ... 0 Input signal 6 B7 BOOLEAN 0 Input signal 7 B8 BOOLEAN 0 Input signal 8 B9 BOOLEAN 0 Input signal 9 B10 BOOLEAN 0 Input signal 10 B11 BOOLEAN 0 Input signal 11 B12 BOOLEAN 0 Input signal 12 B13 BOOLEAN 0 Input signal 13 B14 BOOLEAN 0 Input signal 14 B15 BOOLEAN 0 Input signal 15 B16 BOOLEAN 0 Input signal 16 B17 BOOLEAN 0 Input signal 17 B18 BOOLEAN 0 Input signal 18 B19 BOOLEAN 0 Input signal 1...

Page 293: ...is used to generate combinatory expressions with boolean variables The output signal is TRUE if the input signals are different and FALSE if they are equal 3 21 3 3 Signals Table 294 XOR Input signals Name Type Default Description B1 BOOLEAN 0 Input signal 1 B2 BOOLEAN 0 Input signal 2 Table 295 XOR Output signals Name Type Description O BOOLEAN Output signal 3 21 3 4 Settings The function does no...

Page 294: ... BOOLEAN Output signal 3 21 4 4 Settings The function does not have any parameters available in LHMI or PCM600 3 21 5 Rising edge detector R_TRIG 3 21 5 1 Function block Figure 167 Function block 3 21 5 2 Functionality R_TRIG is used as a rising edge detector R_TRIG detects the transition from FALSE to TRUE at the CLK input When the rising edge is detected the element assigns the output to TRUE At...

Page 295: ...n block 3 21 6 2 Functionality F_TRIG is used as a falling edge detector The function detects the transition from TRUE to FALSE at the CLK input When the falling edge is detected the element assigns the Q output to TRUE At the next execution round the output is returned to FALSE despite the state of the input 3 21 6 3 Signals Table 300 F_TRIG Input signals Name Type Default Description CLK BOOLEAN...

Page 296: ... for extracting the circuit breaker status information Respectively T_POS_OK is used to validate the intermediate or faulty breaker position Table 302 Cross reference between circuit breaker position and function block output Circuit breaker position Output of the function block T_POS_CL T_POS_OP T_POS_OK Intermediate 00 FALSE FALSE FALSE Close 01 TRUE FALSE TRUE Open 10 FALSE TRUE TRUE Faulty 11 ...

Page 297: ...tion CLOSE BOOLEAN Output signal 3 21 7 4 Settings The function does not have any parameters available in LHMI or PCM600 3 21 8 SR flip flop volatile SR 3 21 8 1 Function block Figure 170 Function block 3 21 8 2 Functionality The SR flip flop output Q can be set or reset from the S or R inputs S input has a higher priority over the R input Output NOTQ is the negation of output Q The statuses of ou...

Page 298: ...cription Q BOOLEAN Q status NOTQ BOOLEAN NOTQ status 3 21 9 RS flip flop volatile RS 3 21 9 1 Function block Figure 171 Function block 3 21 9 2 Functionality The RS flip flop output Q can be set or reset from the S or R inputs R input has a higher priority over the S input Output NOTQ is the negation of output Q The statuses of outputs Q and NOTQ are not retained in the nonvolatile memory 1 Keep s...

Page 299: ...ble 314 RS Output signals Name Type Description Q BOOLEAN Q status NOTQ BOOLEAN NOTQ status 3 22 Mathematical operators 3 22 1 Real addition ADDR 3 22 1 1 Function block Figure 172 Function block 3 22 1 2 Functionality The real addition function ADDR adds the inputs REAL_IN1 and REAL_IN2 together ADDR executes the equation REAL_OUT REAL_IN1 REAL_IN2 1 Keep state no change 1MRS759142 F Basic functi...

Page 300: ...OOLEAN Output validity 3 22 2 Real division DIVR 3 22 2 1 Function block Figure 173 Function block 3 22 2 2 Functionality The real division function DIVR divides the REAL_IN1 input by REAL_IN2 DIVR executes the equation REAL OUT REAL IN REAL IN _ _ _ 1 2 Equation 8 If the denominator value is less than 0 001 the resultant quotient is considered out of range If the value of the quotient is outside ...

Page 301: ...al input REAL_IN2 together MULR executes the equation REAL_OUT REAL_IN1 x REAL_IN2 If the value of the product is outside the range then the output quality is set as bad and VALID is set to FALSE The minimum negative product value is restricted to 2097152 000 and the maximum positive product value is restricted to 2097152 000 3 22 3 3 Signals Table 319 MULR Input signals Name Type Default Descript...

Page 302: ... to FALSE The minimum negative difference value is restricted to 2097152 000 and the maximum positive difference value is restricted to 2097152 000 3 22 4 3 Signals Table 321 SUBR Input signals Name Type Default Description REAL_IN1 FLOAT32 0 Real input 1 REAL_IN2 FLOAT32 0 Real input 2 Table 322 SUBR Output signals Name Type Description REAL_OUT FLOAT32 Real output VALID BOOLEAN Output validity 3...

Page 303: ...R REAL_IN2 Figure 177 Region of EQR comparison EQR requires a positive value for TOLR otherwise it may not function properly The TOLR value can be set using SETRGAPC EQR function blocks do not have the hysteresis feature Oscillating outputs should be avoided when comparing analog signals that have closely varying values 3 22 5 3 Signals Table 323 EQR Input signals Name Type Default Description REA...

Page 304: ...L_IN2 TOLR OUT 1 else OUT 0 If inputs REAL_IN1 or REAL_IN2 are outside the range then OUT is set to 0 Not equal region REAL_IN2 TOLR REAL_IN2 TOLR REAL_IN2 Max 2097151 000 Min 2097152 000 Not equal region Figure 179 Region of NER comparison NER requires a positive value for TOLR otherwise it may not function properly The TOLR value can be set using SETRGAPC NER function blocks do not have the hyst...

Page 305: ...2 Functionality The real greater than or equal comparator function GER compares the real input REAL_IN1 with the real input REAL_IN2 and activates the binary output OUT if REAL_IN1 is equal to or greater than REAL_IN2 TOLR or greater than input REAL_IN2 That is if REAL_IN1 REAL_IN2 TOLR or REAL_IN1 REAL_IN2 OUT 1 else OUT 0 If inputs REAL_IN1 or REAL_IN2 are outside the range then OUT is set to 0 ...

Page 306: ...Real less than or equal comparator LER 3 22 8 1 Function block Figure 182 Function block 3 22 8 2 Functionality The real less than or equal comparator function LER compares real input REAL_IN1 with the real input REAL_IN2 and activates the binary output OUT if REAL_IN1 is equal to or less than REAL_IN2 TOLR or less than REAL_IN2 input That is if REAL_IN1 REAL_IN2 TOLR or REAL_IN1 REAL_IN2 OUT 1 el...

Page 307: ...le 330 LER Output signals Name Type Description OUT BOOLEAN Output value 3 22 9 Real maximum value selector MAX3R 3 22 9 1 Function block Figure 184 Function block 3 22 9 2 Functionality The real maximum value selector function MAX3R selects the maximum value from three analog values Disconnected inputs and inputs whose quality is bad are ignored If all inputs are disconnected or the quality is ba...

Page 308: ...nality The real minimum value selector function MIN3R selects the minimum value from three analog values Disconnected inputs and inputs whose quality is bad are ignored If all inputs are disconnected or the quality is bad MIN3R output value is set to 221 3 22 10 3 Signals Table 333 MIN3R Input signals Name Type Default Description REAL_IN1 FLOAT32 0 Real input value 1 REAL_IN2 FLOAT32 0 Real input...

Page 309: ...L_IN1 and REAL_IN2 inputs Table 335 SWITCHR CTL_SW value REAL_OUT value TRUE 1 REAL_IN1 FALSE 0 REAL_IN2 3 22 11 3 Signals Table 336 SWITCHR Input signals Name Type Default Description CTL_SW BOOLEAN 0 Control Switch REAL_IN1 FLOAT32 0 Real input value 1 REAL_IN2 FLOAT32 0 Real input value 2 Table 337 SWITCHR Output signals Name Type Description REAL_OUT FLOAT32 Real switch output 1MRS759142 F Bas...

Page 310: ...cription CTL_SW BOOLEAN 0 Control Switch INT_IN1 INT32 0 Integer input value 1 INT_IN2 INT32 0 Integer input value 2 Table 340 SWITCHI32 Output signals Name Type Description INT_OUT INT32 Integer switch output 3 23 Factory settings restoration In case of configuration data loss or any other file system error that prevents the protection relay from working properly the whole file system can be rest...

Page 311: ...load quantities can be selected for recording and storing in a nonvolatile memory The value range for the recorded load quantities is about eight times the nominal value and values higher than that saturate The recording time depends on a settable demand interval parameter and the amount of quantities selected The record output is in the COMTRADE format 3 24 3 1 Quantities Table 341 Signals suppor...

Page 312: ...stops recording it and the previously collected data are cleared 3 24 3 2 Length of record The recording capability is about 7 4 years when one quantity is recorded and the demand interval is set to 180 minutes The recording time scales down proportionally when a shorter demand time is selected or more quantities are recorded The recording lengths in days with different settings used are presented...

Page 313: ...e PCM600 tool or any appropriate computer software that can access the C LDP COMTRADE folder The load profile record consists of two COMTRADE file types the configuration file CFG and the data file DAT The file name is same for both file types To ensure that both the uploaded file types are generated from the same data content the files need to be uploaded successively Once either of the files is ...

Page 314: ...e load profile record can be enabled or disabled with the Operation setting under the Configuration Load Profile Record menu Any demand output can be connected to any of the quantity channels of the load profile record The mapping is done in Application Configuration in PCM600 Figure 190 Example of a load profile record ACT configuration The memory consumption of load profile record is supervised ...

Page 315: ...ption Rec memory used INT32 0 100 How much recording memory is currently used 3 25 Ethernet channel supervision functions The protection relay offers a bandwidth rate limiting functionality to limit the Ethernet TCP network traffic The main purpose of this feature is the possibility to divide network segments for different multicast frame types and also to limit the network congestion and traffic ...

Page 316: ...y is receiving redundancy supervision frames Otherwise the value is FALSE REDCHLIV BOOLEAN Status of redundant Ethernet channel LAN B When Redundant mode is set to HSR or PRP value is TRUE if the protection relay is receiving redundancy supervision frames Otherwise the value is FALSE LNKLIV BOOLEAN Link status of redundant port LAN A Valid only when Redundant mode is set to HSR or PRP Value is Up ...

Page 317: ...KLIV_A Monitoring Communication Ethernet Link statuses REDLNKLIV_B 3 25 1 6 Diagnostics Diagnostics data is available in Monitoring Communication Ethernet Diagnostics A_B Table 348 Diagnostic parameters for the redundant Ethernet channels LAN A and LAN B Parameter Values Range Unit Step Default Description Reset counters FALSE TRUE FALSE Reset counters command GOOSE limit count 0 1000000 0 Goose r...

Page 318: ... receiving Ethernet frames Otherwise the value is FALSE LNK1LIV BOOLEAN Link status of Ethernet port X1 LAN Value is Up or Down Table 350 SCHLCCH2 Output signals Name Type Description CH2LIV BOOLEAN Status of Ethernet channel X2 LAN When Re dundant mode is set to None or port is not one of the redundant ports LAN A or LAN B value is TRUE if the port is receiving Ethernet frames Otherwise the value...

Page 319: ...nication Ethernet Link statuses LNK1LIV Monitoring Communication Ethernet Link statuses LNK2LIV Monitoring Communication Ethernet Link statuses LNK3LIV 3 25 2 6 Diagnostics Diagnostics data is available in Monitoring Communication Ethernet Diagnostics Xn n 1 3 Table 353 Diagnostic parameters for X1 LAN X2 LAN and X3 LAN Parameter Values Range Unit Step Default Description Reset counters FALSE TRUE...

Page 320: ...ight timeout under Configuration HMI The HMI remains in normal operation mode as long as there is user input from the HMI or a wake up signal before the time set with Backlight timeout elapses The signal used to wake up the HMI is boolean rising edge The wake up can be triggered only after the connected signal has been in FALSE state for longer than a single function cycle The input signal ALM_ACK...

Page 321: ...ALM_ACKED is activated when any alarms are acknowledged either by the boolean rising edge on the ALM_ACK input or by acknowledging alarms from the HMI This generates a one second boolean TRUE value pulse After one second the output is reset to FALSE until some alarms are acknowledged There is at least a 100 ms FALSE state between each pulse If alarms are acknowledged from the HMI during the TRUE s...

Page 322: ...ription HOME BOOLEAN HMI home button indicator WOKEN BOOLEAN HMI woken indicator CONNECTION BOOLEAN HMI connection status indicator ALM_ACKED BOOLEAN Alarms acknowledged indicator 3 26 6 Settings Table 356 HMI configuration parameters Parameter Description Backlight brightness Controls the HMI maximum backlight brightness Actual brightness can be lower due to thermal compensation Enable USB access...

Page 323: ...1 1 Changes to this setting are available only on the HMI 3 27 HMI Ethernet channel supervision HMILCCH 3 27 1 Function block HMILCCH1 HMICHLIV HMILNKLIV O 115 T 2 5 I 1 Figure 195 Function block 3 27 2 Functionality Ethernet channel supervision HMILCCH represents the X0 HMI Ethernet channel 3 27 3 Signals Table 358 HMILCCH Output signals Name Type Description HMICHLIV BOOLEAN Status of the Ethern...

Page 324: ...ferential communication port supervision SCHLCCH6 3 28 1 Function block O 166 T 2 5 I 6 CH6LIV LNK6LIV SCHLCCH6 Figure 196 Function block 3 28 2 Functionality Line differential channel supervision function SCHLCCH6 represents the X6 LD line differential channel 3 28 3 Signals Table 360 SCHLCCH6 Output signals Name Type Description CH6LIV BOOLEAN Status of the line differential port X5 LD Val ue is...

Page 325: ... age Bias current 0 0 131 0 mA 0 Measured SFP transceiver bias current Tx power 0 000 6 550 MW 0 Measured SFP transceiver s transmitter power Rx power 0 000 6 550 mW 0 Measured SFP transceiver s re ceiver power XCVR detected FALSE TRUE FALSE SFP Transceiver detection state Rx Power alarm FALSE TRUE FALSE SFP Receiver power alarm Tx Power alarm FALSE TRUE FALSE SFP Transmitter power alarm Voltage a...

Page 326: ...7 Function block 4 1 1 3 Functionality The three phase non directional overcurrent protection function PHxPTOC is used as one phase two phase or three phase non directional overcurrent and short circuit protection The function starts when the current exceeds the set limit The operate time characteristics for low stage PHLPTOC and high stage PHHPTOC can be selected to be either definite time DT or ...

Page 327: ...on principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The operation of PHxPTOC can be described by using a module diagram All the modules in the diagram are explained in the next sections OPERATE Level detector Phase selection logic BLOCK START ENA_MULT t Timer t I3P I_A I_B I_C Blocking logic Figure 198 Functional module...

Page 328: ... in the DT mode or the maximum value defined by the inverse time curve the OPERATE output is activated When the user programmable IDMT curve is selected the operation time characteristics are defined by the parameters Curve parameter A Curve parameter B Curve parameter C Curve parameter D and Curve parameter E If a drop off situation happens that is a fault suddenly disappears before the operate d...

Page 329: ... time The value is available in the monitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting in Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the protection ...

Page 330: ...T characteristics can be chosen by selecting the Operating curve type values ANSI Def Time or IEC Def Time The functionality is identical in both cases The timer characteristics supported by different stages comply with the list in the IEC 61850 7 4 specification indicate the characteristics supported by different stages Table 364 Timer characteristics supported by different stages Operating curve...

Page 331: ...cted to the power system for example shunt capacitor banks shunt reactors and motors General backup protection PHxPTOC is used for single phase two phase and three phase non directional overcurrent and short circuit protection Typically overcurrent protection is used for clearing two and three phase short circuits Therefore the user can choose how many phases at minimum must have currents above th...

Page 332: ...an 12xI n depending on the fault location and transformer impedance Consequently the protection must operate as fast as possible taking into account the selectivity requirements switching in currents and the thermal and mechanical withstand of the transformer and outgoing feeders Traditionally overcurrent protection of the transformer has been arranged as shown in Figure 200 The low set stage PHLP...

Page 333: ...otection relay the backup overcurrent protection is implemented with four overcurrent stages so that under normal conditions that is when the line differential communication is healthy only two lowest stages are available for the remote backup protection In case a line differential communication failure exists two more stages are released for rapid local backup overcurrent and short circuit protec...

Page 334: ...protection principle The additional time selective stages on the transformer HV and LV sides provide increased security degree of backup protection for the transformer busbar and also for the outgoing feeders Depending on the overcurrent stage in question the selectivity of the scheme in Figure 202 is based on the operating current operating time or blockings between successive overcurrent stages ...

Page 335: ...tie relay unit trips the tie breaker in the above 100 ms which reduces the fault current to a half After this the incoming feeder relay unit of the faulted bus section trips the breaker in approximately 250 ms relaying time which becomes the total fault clearing time in this case Figure 202 Numerical overcurrent protection functionality for a typical sub transmission distribution substation feeder...

Page 336: ...nt protection are adequate sensitivity and operation speed taking into account the minimum and maximum fault current levels along the protected line selectivity requirements inrush currents and the thermal and mechanical withstand of the lines to be protected In many cases the above requirements can be best fulfilled by using multiple stage overcurrent units Figure 203 shows an example of this A b...

Page 337: ...tion characteristics All the points mentioned earlier required to define the overcurrent protection parameters can be expressed simultaneously in a coordination plan In Figure 204 the coordination plan shows an example of operation characteristics in the LV side incoming feeder and radial outgoing feeder 1MRS759142 F Protection functions REX640 Technical Manual 337 ...

Page 338: ...N 0 False Block signal for acti vating the blocking mode ENA_MULT BOOLEAN 0 False Enable signal for cur rent multiplier PHHPTOC Input signals Table 368 PHHPTOC Input signals Name Type Default Description I3P SIGNAL Three phase currents BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode ENA_MULT BOOLEAN 0 False Enable signal for cur rent multiplier Protection functions 1MRS759142 ...

Page 339: ...Output signals Table 371 PHHPTOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start PHIPTOC Output signals Table 372 PHIPTOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start 4 1 1 10 Settings PHLPTOC Settings Table 373 PHLPTOC Group settings Basic Parameter Values Range Unit Step Default Description Start value 0 05 10 00 xIn 0 01 0 05 ...

Page 340: ...e 1 Immediate 2 Def time reset 3 Inverse reset 1 Immediate Selection of reset curve type Table 375 PHLPTOC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Num of start pha ses 1 1 out of 3 2 2 out of 3 3 3 out of 3 1 1 out of 3 Number of phases required for oper ate activation Curve parameter A 0 0086 50000 000 0 0 0001 28 20...

Page 341: ...SI Ext inv 3 ANSI Norm inv 5 ANSI Def Time 9 IEC Norm inv 10 IEC Very inv 12 IEC Ext inv 15 IEC Def Time 17 Programmable 15 IEC Def Time Selection of time delay curve type Table 378 PHHPTOC Group settings Advanced Parameter Values Range Unit Step Default Description Type of reset curve 1 Immediate 2 Def time reset 3 Inverse reset 1 Immediate Selection of reset curve type Table 379 PHHPTOC Non grou...

Page 342: ...t Step Default Description Start value 0 10 40 00 xIn 0 01 1 00 Start value Start value Mult 0 8 10 0 0 1 1 0 Multiplier for scal ing the start value Operate delay time 20 300000 ms 10 20 Operate delay time Table 382 PHIPTOC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Num of start pha ses 1 1 out of 3 2 2 out of 3 3 3 out...

Page 343: ...T32 0 00 100 00 Ratio of start time op erate time PHIPTOC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 1 1 12 Technical data Table 387 PHxPTOC Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured current fn 2 Hz PHLPTOC 1 5 of the set value or 0 002 In PHHPTOC and PHIPTOC 1 5 of set value or 0 002 In at currents in the range of 0 1 10 In 5 0...

Page 344: ...3 Technical revision history Table 388 PHLPTOC Technical revision history Product connectivi ty level Technical revision Change PCL4 G Setting Start value maximum value extended to 10 00xIn 4 1 2 Three phase directional overcurrent protection DPHxPDOC ANSI 67P 51P 1 67P 51P 2 1 Measurement mode default depends on stage current before fault 0 0 In fn 50 Hz fault current in one phase with nominal fr...

Page 345: ...racteristics for low stage DPHLPDOC and high stage DPHHPDOC can be selected to be either definite time DT or inverse definite minimum time IDMT In the DT mode the function operates after a predefined operate time and resets when the fault current disappears The IDMT mode provides current dependent timer characteristics The function contains a blocking functionality It is possible to block function...

Page 346: ...rresponding parameter values are On and Off The operation of DPHxPDOC can be described using a module diagram All the modules in the diagram are explained in the next sections ENA_MULT BLOCK Level detector NON_DIR OPERATE START Phase selection logic t Timer t I3P I_A I_B I2 U3P U_A_AB U_B_BC U_C_CA U1 U2 Blocking logic Directional calculation I_C DIRECTION FAULT_DIR Figure 206 Functional module di...

Page 347: ...h the Voltage Mem time setting DPHxPDOC is provided with a memory function to secure a reliable and correct directional protection relay operation in case of a close short circuit or an earth fault characterized by an extremely low voltage At sudden loss of the polarization quantity the angle difference is calculated on the basis of a fictive voltage The fictive voltage is calculated using the pos...

Page 348: ...e 207 Operating zones at minimum magnitude levels The DIRECTION output indicates on which operating sector the current is measured The value combines phase specific directions which are available in monitored data as DIR_A DIR_B and DIR_C Level detector The measured phase currents are compared phasewise to the set Start value If the measured value exceeds the set Start value the level detector rep...

Page 349: ...ART output Depending on the value of the Operating curve type setting the time characteristics are according to DT or IDMT When the operation timer has reached the value of Operate delay time in the DT mode or the maximum value defined by the inverse time curve the OPERATE output is activated When the user programmable IDMT curve is selected the operation time characteristics are defined by the pa...

Page 350: ...s for overcurrent protection in this manual The timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operating time The value is available in the monitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting in Configurati...

Page 351: ...from the Characteristic angle setting In the backward operation area the Max reverse angle setting gives the counterclockwise sector and the Min reverse angle setting gives the corresponding clockwise sector a measurement from the Characteristic angle setting that has been rotated 180 degrees Figure 209 Configurable operating sectors Table 393 Momentary per phase direction value for monitored data...

Page 352: ...forward 2 backward The direction information DIR_X for some phase is forward and for some phase is reverse 3 both FAULT_DIR gives the detected direction of the fault during fault situations that is when the START output is active Self polarizing as polarizing method Table 395 Equations for calculating angle difference for self polarizing method Faulted phases Used fault current Used polarizi ng vo...

Page 353: ...eed to rotate the polarizing quantity Figure 210 Single phase earth fault phase A In an example case of a two phase short circuit failure where the fault is between phases B and C the angle difference is measured between the polarizing quantity U BC and operating quantity IB IC in the self polarizing method Figure 211 Two phase short circuit short circuit is between phases B and C 1MRS759142 F Pro...

Page 354: ... IB U BC UCA ANGLE A U U I I BC CA A B RCA o _ ϕ ϕ ϕ 90 Equation 18 B C I B IC U CA UAB ANGLE B U U I I CA AB B C RCA o _ ϕ ϕ ϕ 90 Equation 19 C A I C IA U AB UBC ANGLE C U U I I AB BC C A RCA o _ ϕ ϕ ϕ 90 Equation 20 The angle difference between the polarizing quantity U BC and operating quantity I A is marked as φ in an example of the phasors in a single phase earth fault where the faulted phase...

Page 355: ...e phasors in a two phase short circuit failure where the fault is between the phases B and C the angle difference is measured between the polarizing quantity UAB and operating quantity IB IC marked as φ 1MRS759142 F Protection functions REX640 Technical Manual 355 ...

Page 356: ...rence This is done automatically with a system parameter Phase rotation Negative sequence voltage as polarizing quantity When the negative voltage is used as the polarizing quantity the angle difference between the operating and polarizing quantity is calculated with the same formula for all fault types ANGLE X U I RCA _ ϕ ϕ ϕ 2 2 Equation 21 This means that the actuating polarizing quantity is U2...

Page 357: ...able 397 Equations for calculating angle difference for positive sequence quanti ty polarizing method Faulted phases Used fault current Used polarizi ng voltage Angle difference A I A U 1 ANGLE A U I A RCA _ ϕ ϕ ϕ 1 Equation 22 B I B U 1 ANGLE B U I B RCA _ ϕ ϕ ϕ 1 120o Equation 23 C I C U 1 ANGLE C U IC RCA _ ϕ ϕ ϕ 1 120o Equation 24 A B I A IB U 1 ANGLE A U I I A B RCA _ ϕ ϕ ϕ 1 30o Equation 25 ...

Page 358: ...ference needs to be changed The network rotating direction is defined with a system parameter Phase rotation The change in the network rotating direction affects the phase to phase voltages polarization method where the calculated angle difference needs to be rotated 180 degrees Also when the sequence components are used which are the positive sequence voltage or negative sequence voltage componen...

Page 359: ...nt calculations are needed There are situations with no possibility to have the selectivity with a protection system based on overcurrent protection relays in a closed ring system In some applications the possibility of obtaining the selectivity can be improved significantly if DPHxPDOC is used This can also be done in the closed ring networks and radial networks with the generation connected to t...

Page 360: ...ity distribution for the consumers is secured during network fault situations The power is fed at least from two directions which means that the current direction can be varied The time grading between the network level stages is challenging without unnecessary delays in the time settings In this case it is practical to use the directional overcurrent protection relays to achieve a selective prote...

Page 361: ...DPHLPDOC Input signals Name Type Default Description I3P SIGNAL Three phase currents U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode ENA_MULT BOOLEAN 0 False Enable signal for cur rent multiplier NON_DIR BOOLEAN 0 False Forces protection to non directional 1MRS759142 F Protection functions REX640 Technical Manual 361 ...

Page 362: ...ected fault direction DIRECTION Enum Direction information DPHHPDOC Output signals Table 401 DPHHPDOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start FAULT_DIR Enum Detected fault direction DIRECTION Enum Direction information 4 1 2 10 Settings DPHLPDOC Settings Table 402 DPHLPDOC Group settings Basic Parameter Values Range Unit Step Default Description Start value...

Page 363: ...cteristic an gle Max forward angle 0 90 deg 1 80 Maximum phase angle in forward di rection Max reverse angle 0 90 deg 1 80 Maximum phase angle in reverse di rection Min forward angle 0 90 deg 1 80 Minimum phase an gle in forward di rection Min reverse angle 0 90 deg 1 80 Minimum phase an gle in reverse direc tion Table 403 DPHLPDOC Group settings Advanced Parameter Values Range Unit Step Default D...

Page 364: ...te time 20 60000 ms 1 20 Minimum operate time for IDMT curves Reset delay time 0 60000 ms 1 20 Reset delay time Measurement mode 1 RMS 2 DFT 3 Peak to Peak 2 DFT Selects used meas urement mode Allow Non Dir 0 False 1 True 0 False Allows prot activa tion as non dir when dir info is in valid Min operate current 0 01 1 00 xIn 0 01 0 01 Minimum operating current Min operate volt age 0 01 1 00 xUn 0 01...

Page 365: ...election of reset curve type Voltage Mem time 0 3000 ms 1 40 Voltage memory time Pol quantity 1 Self pol 4 Neg seq volt 5 Cross pol 7 Pos seq volt 5 Cross pol Reference quantity used to determine fault direction Table 408 DPHHPDOC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Curve parameter A 0 0086 120 0000 0 0001 28 2000...

Page 366: ...imum operating voltage 4 1 2 11 Monitored data DPHLPDOC Monitored data Table 410 DPHLPDOC Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time DIR_A Enum 0 unknown 1 forward 2 backward 1 both Direction phase A DIR_B Enum 0 unknown 1 forward 2 backward 1 both Direction phase B DIR_C Enum 0 unknown 1 forward 2 backward 1 both Directio...

Page 367: ...g Calculated angle differ ence Phase A ANGLE_B FLOAT32 180 00 180 00 deg Calculated angle differ ence Phase B ANGLE_C FLOAT32 180 00 180 00 deg Calculated angle differ ence Phase C VMEM_USED BOOLEAN 0 False 1 True Voltage memory in use status DPHHPDOC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 1 2 12 Technical data Table 412 DPHxPDOC Technical data Characteristic Value Operation accu...

Page 368: ...he theoretical value or 20 ms 3 Suppression of har monics DFT 50 dB at f n fn where n 2 3 4 5 4 1 2 13 Technical revision history Table 413 DPHLPDOC Technical revision history Product connectivi ty level Technical revision Change PCL4 G Setting Start value maximum value extended to 10 00xIn 1 Measurement mode and Pol quantity default current before fault 0 0 In voltage before fault 1 0 Un fn 50 Hz...

Page 369: ... starts when the input phase current exceeds a limit which is dynamically calculated based on the measured terminal voltages The operating characteristics can be selected to be either inverse definite minimum time IDMT or definite time DT PHPVOC contains a blocking functionality It is possible to block function outputs timers or the function itself 4 1 3 4 Analog channel configuration PHPVOC has t...

Page 370: ...Effective start value calculator t t Phase selection logic I3P I_A I_B I_C U_AB U_BC U3P U_CA Figure 221 Functional module diagram Effective start value calculator The normal starting current above which the overcurrent protection starts is set through the Start value setting The Effective start value of the current may need to be changed during certain conditions like magnetizing inrush or when t...

Page 371: ...hen the Voltage high limit setting is equal to the Voltage low limit setting The effective start value is calculated based on the equations Voltage level Effective start value I effective U Voltage high limit Start value low U Voltage high limit Start value In this example U represents the measured input voltage This voltage step characteristic is graphically represented in Figure 222 Figure 222 E...

Page 372: ...ltage low limit If Voltage high limit is lower than Voltage low limit the voltage step characteristic is active with Voltage low limit being the cutoff value The value of the setting Start value should always be greater than the setting Start value low Otherwise Start value low is used as the effective start value External input control mode The External input control mode is used to enable voltag...

Page 373: ...tart value Mult setting higher than necessary If the value is too high the function may not operate at all during an inrush followed by a fault no matter how severe the fault is The start value multiplication is normally done when the inrush detection function INRPHAR is connected to the ENA_MULT input Phase selection logic If the fault criteria are fulfilled in the level detector the phase select...

Page 374: ... duration value START_DUR which indicates the percentage ratio of the start situation and the set operating time This output is available in the Monitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting Configuration System Blocking mode which selects the blocking mode The BLOCK input can...

Page 375: ...erator terminal voltages are maintained near the normal levels Voltage slope characteristic is often used as an alternative to impedance protection on small to medium 5 150 MVA size generators to provide backup to the differential protection Other applications of the voltage slope characteristic protection exist in networks to provide better coordination and fault detection than plain overcurrent ...

Page 376: ... Multiplier for scal ing the start value Time multiplier 0 05 15 00 0 01 1 00 Time multiplier in IEC ANSI IDMT curves Operating curve type 1 ANSI Ext inv 2 ANSI Very inv 3 ANSI Norm inv 4 ANSI Mod inv 5 ANSI Def Time 6 L T E inv 7 L T V inv 8 L T inv 9 IEC Norm inv 10 IEC Very inv 11 IEC inv 12 IEC Ext inv 13 IEC S T inv 14 IEC L T inv 15 IEC Def Time 17 Programmable 18 RI type 19 RD type 15 IEC D...

Page 377: ...C Non group settings Advanced Parameter Values Range Unit Step Default Description Measurement mode 1 RMS 2 DFT 3 Peak to Peak 2 DFT Selects used meas urement mode Control mode 1 Voltage control 2 Input control 3 Voltage and in put Ctl 4 No Volt depend ency 1 Voltage control Type of control Minimum operate time 40 60000 ms 1 40 Minimum operate time for IDMT curves Reset delay time 0 60000 ms 1 20 ...

Page 378: ...e 5 0 of the set value or 20 ms Suppression of harmonics 50 dB at f n fn where n 2 3 4 5 4 1 4 Accidental energization protection GAEPVOC ANSI 27 50 4 1 4 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Accidental energization protection GAEPVOC U I 27 50 4 1 4 2 Function block Figure 224 Function block 1 Measurement mode defaul...

Page 379: ...ke turbine blades or gearing teeth Lack of oil may damage the bearings as lube pumps are not in operation when the generator is at a standstill The turning gear oil pumps are not in operation either and the accidental energization may significantly damage the turning gear 4 1 4 4 Analog channel configuration GAEPVOC has two analog group inputs which must be properly configured Table 424 Analog inp...

Page 380: ...enerator returns to service and the voltage exceeds the Disarm set voltage setting the scheme is automatically removed from service Level detector disabled after a time delay Disarm delay time setting and the ARMED output is set to FALSE GAEPVOC must only be activated when the generator is out of service and disabled when the generator is online The setting value of Arm set voltage should be less ...

Page 381: ...ther related power station equipment 4 1 4 7 Signals GAEPVOC Input signals Table 426 GAEPVOC Input signals Name Type Default Description I3P SIGNAL Three phase currents U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode GAEPVOC Output signals Table 427 GAEPVOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start ARMED BO...

Page 382: ...y time 4 1 4 9 GAEPVOC Monitored data Table 431 GAEPVOC Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time GAEPVOC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 1 4 10 Technical data Table 432 GAEPVOC Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured current and voltages f...

Page 383: ... detected by other protection functions and the introduction of the three phase thermal protection for feeders cables and distribution transformers function T1PTTR allows the protected circuit to operate closer to the thermal limits An alarm level gives an early warning to allow operators to take action before the line trips The early warning is based on the three phase current measuring function ...

Page 384: ...am are explained in the next sections The function uses ambient temperature which can be measured locally or remotely Local measurement is done by the protection relay Remote measurement uses analog GOOSE to connect AMB_TEMP input If the quality of remotely measured temperature is invalid or communication channel fails the function uses ambient temperature set in Env temperature Set Thermal counte...

Page 385: ...able laying and ground thermal resistivity Thermal counter The actual temperature at the actual execution cycle is calculated as Θ Θ Θ Θ n n final n t e 1 1 1 τ Equation 32 Θ n calculated present temperature Θ n 1 calculated temperature at previous time step Θ final calculated final temperature with actual current Δt time step between calculation of actual temperature t thermal time constant for t...

Page 386: ...a number of parallel lines This is often used for cable lines where one bay connects several parallel cables By setting the Current multiplier parameter to the number of parallel lines cables the actual current on one line is used in the protection algorithm To activate this option the ENA_MULT input must be activated The ambient temperature can be measured with the RTD measurement The measured te...

Page 387: ...ny risk for the above mentioned risks The thermal overload protection provides information that makes temporary overloading of cables and lines possible The thermal overload protection estimates the conductor temperature continuously This estimation is made by using a thermal model of the line cable that is based on the current measurement If the temperature of the protected object reaches a set w...

Page 388: ...Time constant of the line in seconds Maximum tempera ture 22 0 200 0 C 0 1 90 0 Temperature level for operate Alarm value 20 0 150 0 C 0 1 80 0 Temperature level for start alarm Reclose tempera ture 20 0 150 0 C 0 1 70 0 Temperature for re set of block reclose after operate Table 437 T1PTTR Group settings Advanced Parameter Values Range Unit Step Default Description Current multiplier 1 5 1 1 Curr...

Page 389: ...ked 5 off Status 4 1 5 10 Technical data Table 441 T1PTTR Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured current fn 2 Hz Current measurement 1 5 of the set value or 0 002 In at currents in the range of 0 01 4 00 In Operate time accuracy 1 2 0 of the theoretical value or 0 50 s 4 1 6 Three phase thermal overload protection two time constants T2PTTR...

Page 390: ...rmer cooling is estimated with a thermal model 4 1 6 4 Analog channel configuration T2PTTR has one analog group input which must be properly configured Table 442 Analog inputs Input Description I3P Three phase currents See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if the analog channels are not...

Page 391: ...e phase currents according to the expression Θ final ref ref I I T 2 Equation 35 I highest measured phase current I ref the set value of the Current reference setting T ref the set value of the Temperature rise setting temperature rise C with the steady state current I ref The ambient temperature value is added to the calculated final temperature rise estimation If the total value of temperature i...

Page 392: ... value of the Long time constant setting the long heating cooling time constant The warming and cooling following the two time constant thermal curve is a characteristic of transformers The thermal time constants of the protected transformer are given in seconds with the Short time constant and Long time constant settings The Short time constant setting describes the warming of the transformer wit...

Page 393: ...ure if the ambient temperature measurement value is not connected to the AMB_TEMP input The Env temperature Set setting is also used when the ambient temperature measurement connected to T2PTTR is set to Not in use in the X130 RTD function The temperature calculation is initiated from the value defined with the Initial temperature and Max temperature setting parameters The initial value is a perce...

Page 394: ...e risk of internal phase to phase or phase to earth faults Possible hotspots forming within the transformer degrade the quality of the transformer oil During stressed situations in power systems it is required to overload the transformers for a limited time without any risks The thermal overload protection provides information and makes temporary overloading of transformers possible The permissibl...

Page 395: ...y one that is a single time constant it can be converted to two time constants The single time constant is also used by itself if the p factor Weighting factor p setting is set to zero and the time constant value is set to the value of the Long time constant setting The thermal image corresponds to the one time constant model in that case Table 443 Conversion table between one and two time constan...

Page 396: ...perature Set 50 100 C 1 40 Ambient tempera ture used when no external temper ature measurement available Temperature rise 0 0 200 0 C 0 1 78 0 End temperature rise above ambient Max temperature 22 0 200 0 C 0 1 105 0 Maximum tempera ture allowed for the transformer Operate tempera ture 80 0 120 0 0 1 100 0 Operate tempera ture percent value Alarm temperature 40 0 100 0 0 1 90 0 Alarm temperature p...

Page 397: ... 1 80 0 Initial temperature percent value 4 1 6 9 T2PTTR Monitored data Table 450 T2PTTR Monitored data Name Type Values Range Unit Description TEMP FLOAT32 100 0 9999 9 C The calculated temper ature of the protected object TEMP_RL FLOAT32 0 00 99 99 The calculated temper ature of the protected object relative to the operate level T_OPERATE INT32 0 60000 s Estimated time to oper ate T_ENA_CLOSE IN...

Page 398: ...jam protection function JAMPTOC is used for protecting the motor in stall or mechanical jam situations during the running state When the motor is started a separate function is used for the startup protection and JAMPTOC is normally blocked during the startup period When the motor has passed the starting phase JAMPTOC monitors the magnitude of phase currents The function starts when the measured c...

Page 399: ...P t Timer Blocking logic Figure 232 Functional module diagram Level detector The measured phase currents are compared to the set Start value The TRMS values of the phase currents are considered for the level detection The timer module is enabled if at least two of the measured phase currents exceed the set Start value Timer Once activated the internal START signal is activated The value is availab...

Page 400: ... temperature rise in the stator windings Due to reduced speed the temperature also rises in the rotor The rotor temperature rise is more critical when the motor stops The physical and dielectric insulations of the system deteriorate with age and the deterioration is accelerated by the temperature increase Insulation life is related to the time interval during which the insulation is maintained at ...

Page 401: ...escription Reset delay time 0 60000 ms 1 100 Reset delay time 4 1 7 9 JAMPTOC Monitored data Table 457 JAMPTOC Monitored data Name Type Values Range Unit Description START BOOLEAN 0 False 1 True Start START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time JAMPTOC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 1 7 10 Technical data Table 458 JAMPTOC Technical data Characteristic ...

Page 402: ...characteristics which means that the function operates after a predefined operate time and resets when the fault current disappears The function contains a blocking functionality It is possible to block function outputs the definite timer or the function itself 4 1 8 4 Analog channel configuration LOFLPTUC has one analog group input which must be properly configured Table 459 Analog inputs Input D...

Page 403: ...lue of the element Level detector 2 This is a low current detection module which monitors the de energized condition of the motor It compares the phase currents RMS value to the set Start value low setting If any of the phase current values is less than the set Start value low a signal is sent to block the operation of the timer Timer Once activated the timer activates the START output The time ch...

Page 404: ...otor from the power supply instantaneously or after a delay according to the requirement When the motor is at standstill the current will be zero and it is not recommended to activate the trip during this time The minimum current drawn by the motor when it is connected to the power supply is the no load current that is the higher start value current If the current drawn is below the lower start va...

Page 405: ...t Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time 4 1 8 9 LOFLPTUC Monitored data Table 465 LOFLPTUC Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time LOFLPTUC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 1 8 10 Technical data Table 466 LOFLPTUC Technical data Characteristic Value Operation ...

Page 406: ...king functionality It is possible to block function outputs and reset the definite timer 4 1 9 4 Analog input configuration PHPTUC has one analog group input which must be properly configured Table 467 Analog inputs Input Description I3P Three phase currents See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validat...

Page 407: ... the 1 phase mode any of the phase current values are less than the value of the Start value setting the condition is detected and an enable signal is sent to the timer This signal is disabled after all the phase currents have exceeded the set Start value value of the element The protection relay does not accept the Start value to be smaller than Current block value Level detector 2 This is a low ...

Page 408: ...or a quick fuse replacement and saves the asset The Current block value setting can be set to zero to not block PHPTUC with a low three phase current However this results in an unnecessary event sending when the transformer or protected object is disconnected Phase specific start and operate can give a better picture about the evolving faults when one phase has started first and another follows PH...

Page 409: ... Three Phase Number of phases needed to start Table 472 PHPTUC Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time 4 1 9 9 Monitored data Table 473 PHPTUC Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time operate time PHPTUC Enum 1 on 2 blocked 3 test 4 test blocked...

Page 410: ...on the basis of the measured load current and disconnects the motor when the thermal content reaches 100 percent The thermal overload conditions are the most often encountered abnormal conditions in industrial motor applications The thermal overload conditions are typically the result of an abnormal rise in the motor running current which produces an increase in the thermal dissipation of the moto...

Page 411: ...unction uses ambient temperature set in Env temperature Set Internal FLC calculator Thermal level calculator Alarm and tripping logic ALARM OPERATE BLK_RESTART START_EMERG BLOCK AMB_TEMP I3P I_B Max current selector I_A TEMP_RL I_C I2 Figure 238 Functional module diagram Max current selector Max current selector selects the highest measured TRMS phase current and reports it to Thermal level calcul...

Page 412: ...amb 40 100 65 C FLC x 0 75 The ambient temperature is used for calculating thermal level and it is available in the monitored data view from the TEMP_AMB output The activation of the BLOCK input does not affect the TEMP_AMB output The Env temperature Set setting is used If the ambient temperature measurement value is not connected to the AMB_TEMP input in ACT When the ambient temperature measureme...

Page 413: ...linearly from θ A to θ B with a speed of 1 66 percent per second For the motor at standstill that is when the current is below the value of 0 12 x I r the cooling is expressed as θ θ τ 02 e t Equation 40 θ 02 initial thermal level when cooling begins Figure 239 Thermal behavior The required overload factor and negative sequence current heating effect factor are set by the values of the Overload fa...

Page 414: ...e start up condition is available in the monitored data view at the THERMLEV_ST and THERMLEV_END outputs respectively The activation of the BLOCK input does not have any effect on these outputs Alarm and tripping logic The module generates alarm restart inhibit and tripping signals When the thermal level exceeds the set value of the Alarm thermal value setting the ALARM output is activated Sometim...

Page 415: ...Tau 3840 1920 960 640 480 320 160 80 s Figure 240 Trip curves when no prior load and p 20 100 Overload factor 1 05 1MRS759142 F Protection functions REX640 Technical Manual 415 ...

Page 416: ...Tau 3840 1920 960 80 160 320 480 640 s Figure 241 Trip curves at prior load 1 x FLC and p 100 Overload factor 1 05 Protection functions 1MRS759142 F 416 REX640 Technical Manual ...

Page 417: ...rt high ambient temperature restricted motor ventilation reduced speed operation frequent starting or jogging high or low line voltage or frequency mechanical failure of the driven load improper installation and unbalanced line voltage or single phasing The protection of insulation failure by the implementation of current sensing cannot detect some of these conditions such as restricted ventilatio...

Page 418: ...al capacity is used when the motor is running at full load Thus by setting Weighting factor p to 50 percent the protection relay notifies a 45 to 50 percent thermal capacity use at full load For direct on line started motors with hot spot tendencies the value of Weighting factor p is typically set to 50 percent which will properly distinguish between short time thermal stress and long time thermal...

Page 419: ...gative sequence factor During the unbalance condition the symmetry of the stator currents is disturbed and a counter rotating negative sequence component current is set up An increased stator current causes additional heating in the stator and the negative sequence component current excessive heating in the rotor Also mechanical problems like rotor vibration can occur The most common cause of unba...

Page 420: ...The same as the start up current at the beginning of the motor start up For example if the rated current of a motor is 230 A start up current is 5 7 x I r NegativeSeq factor 175 5 7 5 4 2 Equation 43 Setting the thermal restart level The restart disable level can be calculated as follows θ i startuptimeof the motor operatetimewhen no prior load 100 10 0 0 margin Equation 44 For example the motor s...

Page 421: ...ure used in the cal culation MPTTR Output signals Table 479 MPTTR Output signals Name Type Description OPERATE BOOLEAN Operate ALARM BOOLEAN Thermal Alarm BLK_RESTART BOOLEAN Thermal overload indicator to inhibit restart TEMP_RL FLOAT32 The calculated temperature of the protected object rela tive to the operate level 4 1 10 8 MPTTR Settings Table 480 MPTTR Group settings Basic Parameter Values Ran...

Page 422: ...TR Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 482 MPTTR Non group settings Advanced Parameter Values Range Unit Step Default Description Current reference 0 30 2 00 xIn 0 01 1 00 Rated current FLC of the motor Initial thermal Val 0 0 100 0 0 1 74 0 Initial thermal level of the motor 4 1 10 9 MPTTR Monitored data Ta...

Page 423: ... RPTTR ANSI 49R 4 1 11 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Thermal overload protection for ro tors RPTTR 3Ith R 49R 4 1 11 2 Function block Figure 244 Function block 4 1 11 3 Functionality The thermal overload protection for rotors RPTTR protects the rotor of the induction motor from overheating RPTTR models the roto...

Page 424: ...nabled and disabled with the Operation setting The corresponding parameter values are on and off The operation of RPTTR can be described using a module diagram All the modules in the diagram are explained in the next sections The function uses ambient temperature which can be measured locally or remotely Local measurement is done by the protection relay Remote measurement uses analog IEC 61850 8 1...

Page 425: ...vated The OPERATE output is deactivated when the value of the measured current falls below 12 percent of Current reference or the thermal content drops below 100 percent The activation of the BLOCK input blocks the ALARM BLK_RESTART and OPERATE outputs Thermal level calculator The module calculates the thermal load based on the rotor resistances factors true RMS and negative sequence current The r...

Page 426: ...be understood from Figure 246 A B Thermal capacity 100 80 60 Thermal level For e g at Startup Thermal level For e g at Standstill Figure 246 Thermal behavior The required Overload factor is used to define the highest permissible continuous load The recommended value is at minimum 1 05 In order to accurately calculate the rotor thermal condition different time constants are used in the above equati...

Page 427: ...er ambient temperature even at or below rated load can subject the motor windings to excessive temperature The motor rating has to be appropriately reduced for operation in such high ambient temperatures Similarly when the ambient temperature is considerably lower than the nominal 40 C the motor can be slightly overloaded For calculating thermal level it is better that the FLC values are scaled fo...

Page 428: ...l values for slip estimation are rotor resistance at locked rotor and rotor resistance at nominal speed calculated with following equations Settings mentioned in equations can be found from the motor datasheet information 1 Equation 48 RN is the rotor resistance at nominal speed RPMN is the setting Nominal speed and RPMS is the setting Synchronous speed 2 Equation 49 RL is the rotor resistance at ...

Page 429: ...tor resistances depend on the relation of the rotating magnetic fluxes and the rotor speed i e slip The faster the fluxes cut the rotor bars the higher amplitude and higher frequency currents are induced to the rotor bars The rotor positive sequence resistance factor Rr is at its highest at motor standstill S 1 and smallest when the slip is at nominal value S 0 The rotor negative sequence resistan...

Page 430: ...mplementation of current sensing alone cannot detect all of these conditions such as restricted ventilation Similarly protection by sensing temperature alone may be inadequate in cases like frequent starting or jogging Thermal overload protection addresses these deficiencies to a large extent by deploying a rotor thermal model based on load current and the load voltage Rotor thermal level is calcu...

Page 431: ...otor time for warm start The Weighting factor p for the rotor is usually lower than for the stator since the temperature limit for the rotor is often higher Therefore the used thermal capacity when running at full load can be quite low For example with warm and cold locked rotor times being 5 and 6 seconds and Overload factor being 1 05 the Weighting factor p could be set to 18 4 ℎ 1 052 1 5 6 100...

Page 432: ...larm level Tripping due to high overload can be avoided by reducing the load of the motor when the thermal level reaches a set alarm level The Alarm thermal value can be set to a level which will allow the use of the motor s full thermal capacity without causing a trip due to long time overload Generally the Alarm thermal value is set to 80 90 of the trip level 4 1 11 7 Signals RPTTR Input signals...

Page 433: ...le Overload factor 1 00 1 20 0 01 1 05 Overload factor k Alarm value 50 0 100 0 0 1 95 0 Temperature level for start alarm Restart thermal Val 20 0 80 0 0 1 40 0 Thermal level above which function in hibits motor re starting Weighting factor p 20 0 100 0 0 1 50 0 Weighting factor p Time constant nor mal 80 10000 s 1 320 Rotor time con stant during the normal operation of motor Time constant start ...

Page 434: ...it Description TEMP_AMB FLOAT32 99 999 C The ambient tempera ture used in the calcula tion THERMLEV_ST FLOAT32 0 00 9 99 Thermal level at begin ning of motor startup THERMLEV_END FLOAT32 0 00 9 99 Thermal level at the end of motor startup situa tion T_ENARESTART INT32 0 99999 s Estimated time to reset of block restart I_REF_CLC FLOAT32 0 1 3 0 Adjusted Rated current FLC of the motor RPTTR Enum 1 o...

Page 435: ...ft current to the set alarm and operate levels Operate time characteristics are according to definite time DT 4 1 12 4 Analog channel configuration GSLPTOC has one analog input which must be properly configured Table 495 Analog inputs Input Description ISHFT Measured shaft current 4 1 12 5 Operation principle The Operation setting is used to enable or disable the function When selected On the func...

Page 436: ...available harmonics are available in monitored data under I_SHAFT_H1 I_SHAFT_H3 and I_SHAFT_H5 Level detector 1 The module compares the measured shaft current to the setting Operate start value which is set in primary amps If the level exceeds the set value a enable signal is sent to Timer 1 module Level detector 2 The module compares the measured shaft current to the setting Alarm start value whi...

Page 437: ...ding point and with turbogenerators the shaft can be grounded with a slip ring However the leakage current can still occur if the bearing pedestal which is isolated from the ground becomes grounded This imposes shaft voltage on the oil film of the bearing The current can break the insulation that the oil film provides and thus it can cause pitting and abrasion on the bearing face The measured shaf...

Page 438: ...es over 0 1 A mm2 start to damage the bearings This can be generalized so that currents over 1 A can be considered harmful Therefore the recommended setting for Operate start value is 0 5 A and for Alarm start value 0 25 A Both values are set in primary amperes 4 1 12 7 Signals GSLPTOC Input signals Table 496 GSLPTOC Input signals Name Type Default Description ISHFT SIGNAL Analog input BLOCK BOOLE...

Page 439: ...tion 1 on 5 off 1 on Operation Off On Reset delay time 0 10000 ms 1 1000 Reset delay time 4 1 12 9 GSLPTOC Monitored data Table 500 GSLPTOC Monitored data Name Type Values Range Unit Description I_SHAFT FLOAT32 0 00 10 00 A Amplitude of the meas ured shaft current I_SHAFT_H1 FLOAT32 0 00 10 00 A Amplitude of the funda mental component of the measured shaft cur rent I_SHAFT_H3 FLOAT32 0 00 10 00 A ...

Page 440: ...ication Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Non directional earth fault protec tion low stage EFLPTOC Io 51G 51N 1 Non directional earth fault protec tion high stage EFHPTOC Io 51G 51N 2 Non directional earth fault protec tion instantaneous stage EFIPTOC Io 50G 50N 4 2 1 2 Function block Figure 252 Function block 1 Current before fau...

Page 441: ...nalog channel configuration EFxPTOC has one analog group input which must be properly configured Table 502 Analog inputs Input Description IRES Residual current measured or calculated See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do n...

Page 442: ...e curve the OPERATE output is activated When the user programmable IDMT curve is selected the operation time characteristics are defined by the parameters Curve parameter A Curve parameter B Curve parameter C Curve parameter D and Curve parameter E If a drop off situation happens that is a fault suddenly disappears before the operate delay is exceeded the timer reset state is activated The functio...

Page 443: ...ch selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the protection relay s program The influence of the BLOCK signal activation is preselected with the global setting Blocking mode The Blocking mode setting has three blocking methods In the Freeze timers mode the operation timer is frozen to the prevailing value...

Page 444: ...with the list in the IEC 61850 7 4 specification indicate the characteristics supported by different stages Table 504 Timer characteristics supported by different stages Operating curve type EFLPTOC EFHPTOC 1 ANSI Extremely Inverse x x 2 ANSI Very Inverse x 3 ANSI Normal Inverse x x 4 ANSI Moderately Inverse x 5 ANSI Definite Time x x 6 Long Time Extremely Inverse x 7 Long Time Very Inverse x 8 Lo...

Page 445: ...lso applies to solidly earthed networks and earth fault protection of different equipment connected to the power systems such as shunt capacitor bank or shunt reactors and for backup earth fault protection of power transformers Many applications require several steps using different current start levels and time delays EFxPTOC consists of three different protection stages Low EFLPTOC High EFHPTOC ...

Page 446: ...BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode ENA_MULT BOOLEAN 0 False Enable signal for cur rent multiplier EFLPTOC Output signals Table 509 EFLPTOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start EFHPTOC Output signals Table 510 EFHPTOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start EFIPTOC Output signals T...

Page 447: ...nv 15 IEC Def Time 17 Programmable 18 RI type 19 RD type 15 IEC Def Time Selection of time delay curve type Table 513 EFLPTOC Group settings Advanced Parameter Values Range Unit Step Default Description Type of reset curve 1 Immediate 2 Def time reset 3 Inverse reset 1 Immediate Selection of reset curve type Table 514 EFLPTOC Non group settings Basic Parameter Values Range Unit Step Default Descri...

Page 448: ...1 1 0 Multiplier for scal ing the start value Time multiplier 0 025 15 000 0 005 1 000 Time multiplier in IEC ANSI IDMT curves Operate delay time 40 300000 ms 10 40 Operate delay time Operating curve type 1 ANSI Ext inv 3 ANSI Norm inv 5 ANSI Def Time 9 IEC Norm inv 10 IEC Very inv 12 IEC Ext inv 15 IEC Def Time 17 Programmable 15 IEC Def Time Selection of time delay curve type Table 517 EFHPTOC G...

Page 449: ...eas urement mode EFIPTOC Settings Table 520 EFIPTOC Group settings Basic Parameter Values Range Unit Step Default Description Start value 1 00 40 00 xIn 0 01 1 00 Start value Start value Mult 0 8 10 0 0 1 1 0 Multiplier for scal ing the start value Operate delay time 20 300000 ms 10 20 Operate delay time Table 521 EFIPTOC Non group settings Basic Parameter Values Range Unit Step Default Descriptio...

Page 450: ...t 4 test blocked 5 off Status 4 2 1 12 Technical data Table 526 EFxPTOC Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured current fn 2 Hz EFLPTOC 1 5 of the set value or 0 002 In EFHPTOC and EFIPTOC 1 5 of set value or 0 002 In at currents in the range of 0 1 10 In 5 0 of the set value at currents in the range of 10 40 In Start time 1 Minimum Typical...

Page 451: ...istory Table 527 EFLPTOC Technical revision history Product connectivi ty level Technical revision Change PCL4 I Setting Start value maximum value extended to 10 000xIn 4 2 2 Directional earth fault protection DEFxPDEF ANSI 67G N 1 51G N 1 67G N 1 51G N 2 4 2 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Directional earth fa...

Page 452: ...ed to be either definite time DT or inverse definite minimum time IDMT In the DT mode the function operates after a predefined operate time and resets when the fault current disappears The IDMT mode provides current dependent timer characteristics The function contains a blocking functionality It is possible to block function outputs timers or the function itself 4 2 2 4 Analog channel configurati...

Page 453: ...tting VT connection must be Wye in that particular UTVTR Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is...

Page 454: ...e Start value or Start value Mult setting if the product of these settings exceeds the Start value setting range Typically the ENA_MULT input is connected to the inrush detection function INRHPAR In case of inrush INRPHAR activates the ENA_MULT input which multiplies Start value by the Start value Mult setting Directional calculation The directional calculation module monitors the angle between th...

Page 455: ...seq volt is available only in the Phase angle operation mode The directional operation can be selected with the Directional mode setting The alternatives are Non directional Forward and Reverse operation The operation criterion is selected with the Operation mode setting By setting Allow Non Dir to True non directional operation is allowed when the directional information is invalid that is when t...

Page 456: ...g quantity Uo U2 and operating quanti ty Io I2 ANGLE_RCA The angle difference between the operating angle and Char acteristic angle that is ANGLE_RCA ANGLE Characteris tic angle I_OPER The current that is used for fault detection If the Operation mode setting is Phase angle Phase angle 80 or Phase angle 88 I_OPER is the measured or calculated residual current If the Operation mode setting is IoSin...

Page 457: ...s are controlled by the BLOCK input and the global setting in Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the protection relay s program The influence of the BLOCK signal activation is preselected with the global setting Blocking mode The Blocking mode setting has th...

Page 458: ...ngle mode is selected compensated network φRCA 0 deg Characteristic angle 0 deg Figure 256 Definition of the relay characteristic angle RCA 0 degrees in a compensated network Example 2 The Phase angle mode is selected solidly earthed network φRCA 60 deg Characteristic angle 60 deg Protection functions 1MRS759142 F 458 REX640 Technical Manual ...

Page 459: ...elay characteristic angle RCA 60 degrees in a solidly earthed network Example 3 The Phase angle mode is selected isolated network φRCA 90 deg Characteristic angle 90 deg 1MRS759142 F Protection functions REX640 Technical Manual 459 ...

Page 460: ...f 90 degrees compared to the polarizing voltage Consequently the relay characteristic angle RCA should be set to 90 degrees and the operation criteria to IoSin or Phase angle The width of the operating sector in the phase angle criteria can be selected with the settings Min forward angle Max forward angle Min reverse angle or Max reverse angle Figure 259 illustrates a simplified equivalent circuit...

Page 461: ...e the selectivity is based on the measurement of the active current component The magnitude of this component is often small and must be increased by means of a parallel resistor in the compensation equipment When measuring the resistive part of the residual current the Operation mode should be set to Phase angle and the relay characteristic angle RCA should be set to 0 degrees Alternatively the O...

Page 462: ...Iosin Actual operation mode Iosin Actual operation mode Iocos Iocos Actual operation mode Iocos Actual operation mode Iosin Table 533 Characteristic angle control in phase angle operation mode Characteristic angle setting RCA_CTL FALSE RCA_CTL TRUE 90 φ RCA 90 φ RCA 0 0 φ RCA 0 φ RCA 90 Use of the extended phase angle characteristic The traditional method of adapting the directional earth fault pr...

Page 463: ...ical value is 170 degrees Min reverse angle in case Directional mode is set to Reverse The Max forward angle setting should be set to cover the possible measurement inaccuracies of current and voltage transformers a typical value is 80 degrees Max reverse angle in case Directional mode is set to Reverse Figure 261 Extended operation area in directional earth fault protection 4 2 2 7 Measurement mo...

Page 464: ... IEC Def Time The functionality is identical in both cases The following characteristics which comply with the list in the IEC 61850 7 4 specification indicate the characteristics supported by different stages Table 535 Timer characteristics supported by different stages Operating curve type DEFLPDEF DEFHPDEF 1 ANSI Extremely Inverse x x 2 ANSI Very Inverse x 3 ANSI Normal Inverse x x 4 ANSI Moder...

Page 465: ...ectors are defined separately The forward operation area is limited with the Min forward angle and Max forward angle settings The reverse operation area is limited with the Min reverse angle and Max reverse angle settings The sector limits are always given as positive degree values In the forward operation area the Max forward angle setting gives the clockwise sector and the Min forward angle sett...

Page 466: ...d the re verse sectors that is the sectors are overlap ping 3 both If the Allow Non Dir setting is False the directional operation forward reverse is not allowed when the measured polarizing or operating quantities are invalid that is their magnitude is below the set minimum values The minimum values can be defined with the settings Min operate current and Min operate voltage In case of low magnit...

Page 467: ... operation criterion Io sin φ When the Iosin φ or Iocos φ criterion is used the component indicates a forward or reverse type fault through the FAULT_DIR and DIRECTION outputs in which 1 equals a forward fault and 2 equals a reverse fault Directional operation is not allowed the Allow non dir setting is False when the measured polarizing or operating quantities are not valid that is when their mag...

Page 468: ...is limited by angle correction that is the operating sector is 180 degrees 2 angle correction Example 2 Iosin φ criterion selected reverse type fault FAULT_DIR 2 Figure 264 Operating characteristic Iosin φ in reverse fault Protection functions 1MRS759142 F 468 REX640 Technical Manual ...

Page 469: ...LT_DIR 1 Figure 265 Operating characteristic Iocos φ in forward fault Example 4 Iocos φ criterion selected reverse type fault FAULT_DIR 2 Figure 266 Operating characteristic Iocos φ in reverse fault 1MRS759142 F Protection functions REX640 Technical Manual 469 ...

Page 470: ...of the fixed sectors are rounded The sector rounding is used for cancelling the CT measurement errors at low current amplitudes When the current amplitude falls below three percent of the nominal current the sector is reduced to 70 degrees at the fixed sector side This makes the protection more selective which means that the phase angle measurement errors do not cause faulty operation There is no ...

Page 471: ...le settings cannot be set but they have a fixed value of 88 degrees The sector limits of the fixed sectors are rounded Sector rounding in the phase angle 88 consists of three parts If the current amplitude is between 1 20 percent of the nominal current the sector limit increases linearly from 73 degrees to 85 degrees If the current amplitude is between 20 100 percent of the nominal current the sec...

Page 472: ...30 40 50 70 80 90 100 Io of In 0 90 45 30 15 75 60 90 45 30 15 75 60 Min forward angle 10 88 deg 85 deg 73 deg 100 of In 20 of In 1 of In Figure 270 Phase angle 88 amplitude Directional mode Forward Protection functions 1MRS759142 F 472 REX640 Technical Manual ...

Page 473: ...es wide This allows the protection settings to stay the same when the resonance coil is disconnected from between the neutral point and earth System neutral earthing is meant to protect personnel and equipment and to reduce interference for example in telecommunication systems The neutral earthing sets challenges for protection systems especially for earth fault protection In isolated networks the...

Page 474: ...ly the selectivity of the scheme the core balance current transformers should have a transformation ratio of at least 70 1 Lower transformation ratios such as 50 1 or 50 5 are not recommended Attention should be paid to make sure the measuring transformers are connected correctly so that DEFxPDEF is able to detect the fault current direction without failure As directional earth fault uses residual...

Page 475: ...40 DEFHPDEF Input signals Name Type Default Description I3P SIGNAL Three phase currents IRES SIGNAL Residual current U3P SIGNAL Three phase voltages URES SIGNAL Residual voltage BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode ENA_MULT BOOLEAN 0 False Enable signal for cur rent multiplier RCA_CTL BOOLEAN 0 False Relay characteristic angle control DEFLPDEF Output signals Table 5...

Page 476: ...orward Directional mode Time multiplier 0 025 15 000 0 005 1 000 Time multiplier in IEC ANSI IDMT curves Operating curve type 1 ANSI Ext inv 2 ANSI Very inv 3 ANSI Norm inv 4 ANSI Mod inv 5 ANSI Def Time 6 L T E inv 7 L T V inv 8 L T inv 9 IEC Norm inv 10 IEC Very inv 11 IEC inv 12 IEC Ext inv 13 IEC S T inv 14 IEC L T inv 15 IEC Def Time 17 Programmable 18 RI type 19 RD type 15 IEC Def Time Selec...

Page 477: ... Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Curve parameter A 0 0086 120 0000 0 0001 28 2000 Parameter A for customer program mable curve Curve parameter B 0 0000 0 7120 0 0001 0 1217 Parameter B for customer program mable curve Curve parameter C 0 02 2 00 0 01 2 00 Parameter C for customer program mable curve Curve parameter D 0 46 30 00 0 01 29 10 Parameter D ...

Page 478: ...l mode Time multiplier 0 025 15 000 0 005 1 000 Time multiplier in IEC ANSI IDMT curves Operating curve type 1 ANSI Ext inv 3 ANSI Norm inv 5 ANSI Def Time 15 IEC Def Time 17 Programmable 15 IEC Def Time Selection of time delay curve type Operate delay time 40 300000 ms 10 40 Operate delay time Characteristic an gle 179 180 deg 1 90 Characteristic an gle Max forward angle 0 180 deg 1 80 Maximum ph...

Page 479: ... Curve parameter E 0 0 1 0 0 1 1 0 Parameter E for customer program mable curve Table 550 DEFHPDEF Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time Minimum operate time 40 60000 ms 1 40 Minimum operate time for IDMT curves Allow Non Dir 0 False 1 True 0 False Allows prot activa tion as non dir when dir info is in val...

Page 480: ...PDEF Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time ANGLE_RCA FLOAT32 180 00 180 00 deg Angle between operat ing angle and charac teristic angle ANGLE FLOAT32 180 00 180 00 deg Angle between polar izing and operating quantity I_OPER FLOAT32 0 00 40 00 xIn Calculated operating current DEFHPDEF Enum 1 on 2 blocked 3 test 4 test ...

Page 481: ... time accuracy in definite time mode 4 1 0 of the set value or 20 ms Operate time accuracy in inverse time mode 5 0 of the theoretical value or 20 ms 3 Suppression of harmonics RMS No suppression DFT 50 dB at f n fn where n 2 3 4 5 Peak to Peak No suppression 1 Measurement mode default depends on stage current before fault 0 0 In f n 50 Hz earth fault current with nominal frequency injected from r...

Page 482: ...h fault protection function INTRPTEF is a function designed for the protection and clearance of permanent and intermittent earth faults in distribution and sub transmission networks Fault detection is done from the residual current and residual voltage signals by monitoring the transients The operating time characteristics are according to definite time DT The function contains a blocking function...

Page 483: ...h the Operation setting The corresponding parameter values are On and Off The operation of INTRPTEF can be described with a module diagram All the modules in the diagram are explained in the next sections BLK_EF OPERATE BLOCK START Timer 2 t Timer 1 Transient detector Fault indication logic Level detector IRES URES Io Uo Figure 273 Functional module diagram Level detector The Level detector module...

Page 484: ...ection operates when the fault is outside the protected feeder in the background network If the direction has no importance the value Non directional can be selected The detected fault direction FAULT_DIR is available in the monitored data view In the Transient EF mode when the start transient of the fault is detected and the Uo level exceeds the set Voltage start value Timer 1 is activated Timer ...

Page 485: ...additional transient is detected during the drop off cycle The Reset delay time starts to elapse from each detected transient peak In case there is no OPERATE activation for example the fault disappears momentarily START stays activated until the Reset delay time elapses that is reset takes place if time between transients is more than Reset delay time After OPERATE activation a fixed pulse length...

Page 486: ...eactivated Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the protection relay s program The influence of the BLOCK signa...

Page 487: ...initiated as the phase to earth voltage exceeds the reduced insulation level of the fault point and mostly extinguishes itself as the fault current drops to zero for the first time as shown in Figure 276 As a result very short transients that is rapid changes in the form of spikes in residual current Io and in residual voltage Uo can be repeatedly measured Typically the fault resistance in case of...

Page 488: ... Example of earth fault transients including discharge and charge transient components when a permanent fault occurs in a 20 kV network in phase C 4 2 3 7 Signals INTRPTEF Input signals Table 557 INTRPTEF Input signals Name Type Default Description IRES SIGNAL Residual current URES SIGNAL Residual voltage BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode INTRPTEF Output signals ...

Page 489: ... EF Operation criteria Table 561 INTRPTEF Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 40 60000 ms 1 500 Reset delay time Peak counter limit 2 20 1 2 Min requirement for peak counter before start in IEF mode Min operate current 0 01 1 00 xIn 0 01 0 01 Minimum operating current for transi ent detector 4 2 3 9 INTRPTEF Monitored data Table 562 INT...

Page 490: ...ult protection function EFPADM provides a selective earth fault protection function for high resistance earthed unearthed and compensated networks It can be applied for the protection of overhead lines as well as with underground cables It can be used as an alternative solution to traditional residual current based earth fault protection functions such as the IoCos mode in DEFxPDEF Main advantages...

Page 491: ...oup inputs which must be properly configured Table 564 Analog inputs Input Description IRES Residual current measured or calculated URES Residual voltage measured or calculated See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 565 Special conditions Condition Description URES ca...

Page 492: ...by 180 degrees by setting the Pol reversal parameter to True or by switching the polarity of the residual voltage measurement wires As an alternative for the internal residual overvoltage based start condition the neutral admittance protection can also be externally released by utilizing the RELEASE input When Admittance Clc mode is set to Delta the external logic used must be able to give RELEASE...

Page 493: ...otection is required if the network has a high degree of asymmetry during the healthy state or if the residual current measurement is based on sum connection that is the Holmgren connection Neutral admittance calculation produces certain values during forward and reverse faults Fault in reverse direction that is outside the protected feeder Yo Y Fdtot Equation 59 j I U eFd ph Equation 60 Y Fdtot S...

Page 494: ...round network Im Yo Re Yo Reverse fault Yo j IeFd Uph Figure 280 Admittance calculation during a reverse fault R CC Resistance of the parallel resistor L CC Inductance of the compensation coil R n Resistance of the neutral earthing resistor Y Fd Phase to earth admittance of the protected feeder Y Bg Phase to earth admittance of the background network For example in a 15 kV compensated network with...

Page 495: ...ing of the admittance characteristic Fault in the forward direction that is inside the protected feeder Unearthed network Yo Y Bgtot Equation 62 j I I U eTot eFd ph Equation 63 Compensated network Yo Y Y Bgtot CC Equation 64 I j I K I U Rcc eTot eFd ph 1 Equation 65 High resistance earthed network Yo Y Y Bgtot Rn Equation 66 I j I I U Rn eTot eFd ph Equation 67 Y Bgtot Sum of the phase to earth ad...

Page 496: ...nd the leakage losses of the background network and the losses of the coil Theoretically the measured admittance is located in the first or fourth quadrant in the admittance plane depending on the compensation degree see Figure 281 Before the parallel resistor is connected the resistive part of the measured admittance is due to the leakage losses of the background network and the losses of the coi...

Page 497: ... Io Forward Fault Lcc Rcc IeFd IeTot IeTot IeFd Uo Rn Protected feeder Background network YFd YBg Figure 281 Admittance calculation during a forward fault When the network is fully compensated in compensated networks theoretically during a forward fault the imaginary part of the measured admittance equals the susceptance of the protected feeder with a negative sign The discrimination between a for...

Page 498: ...istic When a high sensitivity of the protection is required the residual current should be measured with a cable ring core CT that is the Ferranti CT Also the use of the sensitive Io input should be considered The residual voltage measurement should be done with an open delta connection of the three single pole insulated voltage transformers The sign of the admittance characteristic settings shoul...

Page 499: ...aracteristic The most typical characteristics are highlighted and explained in details in Chapter 4 2 4 6 Neutral admittance characteristics Operation is achieved when the calculated neutral admittance Yo moves outside the characteristic the operation area is marked with gray The settings defining the admittance characteristics are given in primary milliSiemens mS The conversion equation for the a...

Page 500: ...Figure 282 Admittance characteristic with different operation modes when Directional mode Non directional Protection functions 1MRS759142 F 500 REX640 Technical Manual ...

Page 501: ...Figure 283 Admittance characteristic with different operation modes when Directional mode Forward 1MRS759142 F Protection functions REX640 Technical Manual 501 ...

Page 502: ...Figure 284 Admittance characteristic with different operation modes when Directional mode Reverse Protection functions 1MRS759142 F 502 REX640 Technical Manual ...

Page 503: ...n the Block all mode the whole function is blocked and the timers are reset In the Block OPERATE output mode the function operates normally but the OPERATE output is not activated 4 2 4 6 Neutral admittance characteristics The applied characteristic should always be set to cover the total admittance of the protected feeder with a suitable margin However more detailed setting value selection princi...

Page 504: ...at is the boundary line is a vertical line in the admittance plane A positive tilt value rotates the boundary line counterclockwise from the vertical axis In case of non directional conductance criterion the Conductance reverse setting must be set to a smaller value than Conductance forward Operation is achieved when the measured admittance moves over either of the boundary lines The non direction...

Page 505: ...nce characteristic Left figure classical forward directional overconductance criterion Middle figure characteristic is tilted with negative tilt angle Right figure characteristic is tilted with positive tilt angle Forward directional oversusceptance characteristic The forward directional oversusceptance criterion is enabled with the Operation mode setting set to Bo and Directional mode to Forward ...

Page 506: ...d Circle susceptance are 0 0 mS and Conductance tilt Ang equals zero degrees that is the characteristic is a combination of an origin centered circle with two vertical overconductance boundary lines A positive tilt value for the Conductance tilt Ang setting rotates boundary lines counterclockwise from the vertical axis In case of the non directional conductance criterion the Conductance reverse se...

Page 507: ...gle defined with the Conductance tilt Ang and Susceptance tilt Ang settings By default the tilt angles are zero degrees that is the boundary lines are straight lines in the admittance plane A positive Conductance tilt Ang value rotates the overconductance boundary line counterclockwise from the vertical axis A positive Susceptance tilt Ang value rotates the oversusceptance boundary line counterclo...

Page 508: ...tional oversusceptance characteristic The non directional overconductance and non directional oversusceptance characteristic provides a good sensitivity and selectivity when the characteristic is set to cover the total admittance of the protected feeder with a proper margin The sign of the admittance characteristic settings should be considered based on the location of characteristic boundary in t...

Page 509: ... the full resonance and when the parallel resistor of the coil is not connected The residual overvoltage based start condition for the admittance protection enables a multistage protection principle For example one instance of EFPADM could be used for alarming to detect faults with a high fault resistance using a relatively low value for the Voltage start value setting Another instance of EFPADM c...

Page 510: ...r than the absolute value of the capacitive reactance of the network Parallel resistor of the compensation coil is assumed to be disconnected 0 10 20 30 40 50 60 70 80 90100 0 10 20 30 40 50 60 70 80 90 100 Total earth fault current A Rf 0 ohm Residual voltage Resonance K 1 0 10 20 30 40 50 60 70 80 90100 0 10 20 30 40 50 60 70 80 90 100 Total earth fault current A Rf 0 ohm Residual voltage Over U...

Page 511: ...lel resistor Yo Y Y j B Bgtot CC 1 73 mS Equation 74 Where the imaginary part of the admittance B depends on the tuning of the coil compensation degree The admittance characteristic is selected to be the combined overconductance and oversusceptance characteristic Box characteristics with four boundary lines Operation mode Go Bo Directional mode Non directional The admittance characteristic is set ...

Page 512: ...rse This setting should be set based on the value of the maximum earth fault current produced by the feeder considering possible feeder topology changes with a security margin This ensures that the admittance operating point stays inside the Box characteristics during outside fault The recommended security margin should not be lower than 1 5 Susceptance reverse 10 A 1 5 15 kV sqrt 3 1 73 mS Conduc...

Page 513: ...Group settings Basic Parameter Values Range Unit Step Default Description Voltage start value 0 01 2 00 xUn 0 01 0 15 Voltage start value Directional mode 1 Non directional 2 Forward 3 Reverse 2 Forward Directional mode Operation mode 1 Yo 2 Go 3 Bo 4 Yo Go 5 Yo Bo 6 Go Bo 7 Yo Go Bo 1 Yo Operation criteria Operate delay time 60 300000 ms 10 60 Operate delay time Circle radius 0 05 500 00 mS 0 01 ...

Page 514: ...p Default Description Operation 1 on 5 off 1 on Operation Off On Table 572 EFPADM Non group settings Advanced Parameter Values Range Unit Step Default Description Admittance Clc mode 1 Normal 2 Delta 1 Normal Admittance calcula tion mode Reset delay time 0 60000 ms 1 20 Reset delay time Pol reversal 0 False 1 True 0 False Rotate polarizing quantity Min operate current 0 01 1 00 xIn 0 01 0 01 Minim...

Page 515: ...ication Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Rotor earth fault protection injec tion method MREFPTOC Io R 64R 4 2 5 2 Function block Figure 296 Function block 4 2 5 3 Functionality The rotor earth fault protection injection method function MREFPTOC is used to detect an earth fault in the rotor circuit of synchronous machines MREFPTOC ...

Page 516: ...ble signal sources Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 4 2 5 5 Operation principle...

Page 517: ...inary input BLOCK can be used to block the function The activation of the BLOCK input deactivates all outputs and resets the internal timers Timer 2 Once activated the Timer activates the alarm timer The timer characteristic is according to DT When the alarm timer has reached the value set by Alarm delay time in the DT mode the ALARM output is activated If a drop off situation occurs that is a fau...

Page 518: ...nt increases and can reach a level of 130 mA at a fully developed earth fault fault resistance RE 0 one coupling capacitor C1 2μF is used The integrated current transformer of the injection device REK 510 then amplifies this current with the ratio of 1 10 to a measurable level MREFPTOC is used to measure this current An example of the measured curves with various field to earth leakage capacitance...

Page 519: ...he rotor earth fault resistance with various field to earth capacitance values with the measuring circuit resistance Rm 3 0 Ω fn 50 Hz Only one coupling capacitor is used 4 2 5 7 Signals 1MRS759142 F Protection functions REX640 Technical Manual 519 ...

Page 520: ...1 0 010 Alarm start value Operate delay time 40 20000 ms 1 500 Operate delay time Alarm delay time 40 200000 ms 1 10000 Alarm delay time Table 579 MREFPTOC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 580 MREFPTOC Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 6000...

Page 521: ...OC ANSI 51NH 4 2 6 1 Identification Description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Harmonics based earth fault pro tection HAEFPTOC Io HA 51NH 4 2 6 2 Function block Figure 300 Function block 4 2 6 3 Functionality The harmonics based earth fault protection function HAEFPTOC is used instead of a traditional earth fault protection in networks where a fund...

Page 522: ...on HAEFPTOC has one analog group input which must be properly configured Table 583 Analog signals Input Description IRES Residual current measured or calculated See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain s...

Page 523: ...rk for example in a 50 Hz network the cutoff frequency is 100 Hz that is summing the harmonic components of the network from the second harmonic The output of the filter later referred to as the harmonics current is fed to the Level detector and Current comparison modules The harmonics current I_HARM_RES is available in the monitored data view The value is also sent over horizontal communication t...

Page 524: ...t If the locally measured harmonics current is higher than I_REF_RES the enabling signal is sent to Timer If the locally measured harmonics current is lower than I_REF_RES the fault is not in that feeder The detected situation blocks Timer internally and simultaneously also the BLKD_I_REF output is activated The module also supervises the communication channel validity which is reported to the Tim...

Page 525: ...tion may change substantially depending on the user settings When the programmable IDMT curve is selected the operation time characteristics are defined with the Curve parameter A Curve parameter B Curve parameter C Curve parameter D and Curve parameter E parameters If a drop off situation happens that is a fault suddenly disappears before the operation delay is exceeded the Timer reset state is a...

Page 526: ...ection relay s program The influence of the BLOCK signal activation is preselected with the global setting Blocking mode The Blocking mode setting has three blocking methods In the Freeze timers mode the operation timer is frozen to the prevailing value but the OPERATE output is not deactivated when blocking is activated In the Block all mode the whole function is blocked and the timers are reset ...

Page 527: ...c Parameter Values Range Unit Step Default Description Start value 0 05 5 00 xIn 0 01 0 10 Start value Time multiplier 0 025 15 000 0 005 1 000 Time multiplier in IEC ANSI IDMT curves Operate delay time 100 300000 ms 10 600 Operate delay time Operating curve type 1 ANSI Ext inv 2 ANSI Very inv 3 ANSI Norm inv 4 ANSI Mod inv 5 ANSI Def Time 6 L T E inv 7 L T V inv 8 L T inv 9 IEC Norm inv 10 IEC Ve...

Page 528: ...217 Parameter B for customer program mable curve Curve parameter C 0 02 2 00 0 01 2 00 Parameter C for customer program mable curve Curve parameter D 0 46 30 00 0 01 29 10 Parameter D for customer program mable curve Curve parameter E 0 0 1 0 0 1 1 0 Parameter E for customer program mable curve Table 590 HAEFPTOC Non group settings Advanced Parameter Values Range Unit Step Default Description Rese...

Page 529: ...E Po 32N 4 2 7 2 Function block Figure 304 Function block 4 2 7 3 Functionality The wattmetric based earth fault protection function WPWDE can be used to detect earth faults in unearthed networks compensated networks Petersen coil earthed networks or networks with a high impedance earthing It can be used as an alternative solution to the traditional residual current based earth fault protection fu...

Page 530: ...ltage measured or calculated See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 594 Special conditions Condition Description URES calculated The function requires that all three voltage channels are connected for calculating the re sidual voltage Setting VT connection must be Wye...

Page 531: ...larizing quantity after considering the Characteristic angle setting is in the operation sector the module sends an enabling signal to Level detector The directional operation is selected with the Directional mode setting Either the Forward or Reverse operation mode can be selected The direction of fault is calculated based on the phase angle difference between the operating quantity Io and polari...

Page 532: ...mum sensitivity Characteristic angle can be set anywhere between 179 to 180 Thus the effective phase angle ϕ for calculating the residual power considering characteristic angle is according to the equation φ Uo Io Characteristic angle Equation 75 In addition the characteristic angle can be changed via the control signal RCA_CTL The RCA_CTL input is used in the compensated networks where the compen...

Page 533: ...ed only when the correct angle calculation can be made If the magnitude of the operating quantity or polarizing quantity is not high enough the direction calculation is not reliable Hence the magnitude of the operating quantity is compared to the Min operate current setting and the magnitude of the polarizing quantity is compared to Min operate voltage and if both the operating quantity and polari...

Page 534: ...ty and polarizing quantity are exceeded However if the angle calculation is not valid the calculated residual power is zero Residual power RES_POWER is calculated continuously and it is available in the monitored data view The power is given in relation to nominal power calculated as Pn Un In where Un and In are obtained from the entered voltage transformer and current transformer ratios entered L...

Page 535: ... controlled by the BLOCK input and the global setting in Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the protection relay s program The influence of the BLOCK signal activation is preselected with the global setting Blocking mode The Blocking mode setting has three b...

Page 536: ...Figure 309 Operation time curves for wattmetric IDMT for S ref set at 0 15 xPn Protection functions 1MRS759142 F 536 REX640 Technical Manual ...

Page 537: ...n coil L If the coil is tuned exactly to the system capacitance the fault current has only a resistive component This is due to the resistances of the coil and distribution lines together with the system leakage resistances R 0 Often a resistor R L in parallel with the coil is used for increasing the fault current When a single phase to earth fault occurs the capacitance of the faulty phase is byp...

Page 538: ...ement errors and current transformer amplitude are checked first It is not recommended to use the directional wattmetric protection in case of a ring or meshed system as the wattmetric requires a radial power flow to operate The relay characteristic angle needs to be set based on the system earthing In an unearthed network that is when the network is only coupled to earth via the capacitances betw...

Page 539: ...NAL Residual voltage BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode RCA_CTL BOOLEAN 0 False Relay characteristic angle control WPWDE Output signals Table 596 WPWDE Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start 4 2 7 10 WPWDE Settings Table 597 WPWDE Group settings Basic Parameter Values Range Unit Step Default Description Directional mode 2 ...

Page 540: ...eak to Peak 2 DFT Selects used cur rent measurement mode Correction angle 0 0 10 0 deg 0 1 2 0 Angle correction Min operate current 0 010 1 000 xIn 0 001 0 010 Minimum operating current Min operate volt age 0 01 1 00 xUn 0 01 0 01 Minimum operating voltage Reset delay time 0 60000 ms 1 20 Reset delay time Pol reversal 0 False 1 True 0 False Rotate polarizing quantity 4 2 7 11 WPWDE Monitored data ...

Page 541: ...e time mode 3 1 0 of the set value or 20 ms Operate time accuracy in IDMT mode 5 0 of the set value or 20 ms Suppression of harmonics 50 dB at f n fn where n 2 3 4 5 4 2 8 Third harmonic based stator earth fault protection H3EFPSEF ANSI 64TN 4 2 8 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Third harmonic based stator earth ...

Page 542: ...ing functionality Blocking deactivates all outputs and reset timers 4 2 8 4 Analog channel configuration H3EFPSEF has three analog group inputs which must be properly configured Table 602 Analog inputs Input Description U3P 1 Three phase voltages Necessary when Volt age selection is set to Uo Phase A Phase B or Phase C URES 2 Residual voltage measured or calculated Necessary when Voltage selection...

Page 543: ...ed with the Operation setting The corresponding parameter values are On and Off The operation of the third harmonic based stator earth fault protection function can be described using a module diagram All the modules in the diagram are explained in the next sections START BLOCK UNEUT U_3H_N OPERATE Level detector 3rd harmonic calculation Timer Differential calculation U3P U_3H_A U_3H_B U_3H_C GCB_...

Page 544: ...tive phase that is Phase A or Phase B or Phase C based on the available phase In this case the magnitude of the terminal side third harmonic voltage is assumed to be equal to the third harmonic voltage of the phase available U U U U H T H A H B H C 3 3 3 3 _ _ _ _ or or Equation 79 The function is internally blocked if the magnitude of calculated Ū 3H_T is lower than the set Voltage block value Th...

Page 545: ... is available in the Monitored data view Level detector In the third harmonic differential method Level detector compares the third harmonic differential voltage with the third harmonic bias voltage If the differential voltage exceeds the biased voltage the module sends an enabling signal to start the timer If the terminal voltage is not available that is Voltage selection is set to No voltage the...

Page 546: ...ct only 95 of the stator winding leaving 5 of the neutral end unprotected This is because the voltage generated in the faulted winding decreases as the fault point becomes closer to the neutral point and it is not enough to drive the protection Under certain unfavorable conditions the blind zone may extend up to 20 from the neutral point An earth fault close to the neutral point is not dangerous b...

Page 547: ...ages generated the third harmonic voltage has the highest magnitude with the magnitude varying between 1 and 10 of the terminal voltage depending on the generator design philosophy However for a particular generator the magnitude of third harmonics on the neutral side and terminal side depends also on the active power generated Figure 315 Typical example of the third harmonic voltage measured at t...

Page 548: ...ample K 1 5 Equation 85 must be satisfied in the normal healthy condition of the protected generator with a high enough value for K so that no unwanted operation of the protection should be expected regardless the load on the generator To assure a reliable functioning of the protection it is necessary that the generator produces third harmonic voltage which is at least 1 of the generator rated vol...

Page 549: ... Based on the graph such value of the Beta setting must be selected that the bias voltage even in the worst condition is at least 30 to 50 higher than the differential voltage The angle between the third harmonic voltage phasors Ū 3H_T and Ū 3H_N is 150 and with the Beta setting value 1 0 protection guarantees a stability margin of 25 This requires the value of Beta to be increased so as to increa...

Page 550: ...tor winding be tween the generator terminal and earth fault location When there is a generator breaker the capacitive coupling to earth differs between the operating conditions when the generator is running with the generator breaker open before synchronization and with the circuit breaker closed With the generator breaker open the total capacitance is smaller compared to normal operating conditio...

Page 551: ...ltages URES SIGNAL Residual voltage UNEUT SIGNAL Analog input BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode GCB_CLOSED BOOLEAN 0 False Generator CB in closed position H3EFPSEF Output signals Table 605 H3EFPSEF Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start INT_BLKD BOOLEAN Protection internally blocked 4 2 8 8 H3EFPSEF Settings Table 606 H3E...

Page 552: ... CB used 0 No 1 Yes 0 No Defines if genera tor circuit breaker exists Reset delay time 0 60000 ms 1 20 Reset delay time 4 2 8 9 H3EFPSEF Monitored data Table 610 H3EFPSEF Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time UD_3H FLOAT32 0 00 40 00 xUn 3rd harmonic differen tial voltage amplitude UB_3H FLOAT32 0 00 40 00 xUn 3rd har...

Page 553: ...NSI IEEE C37 2 device number Multifrequency admittance based earth fault protection MFADPSDE Io Y 67NYH 4 2 9 2 Function block Figure 318 Function block 4 2 9 3 Functionality The multifrequency admittance based earth fault protection function MFADPSDE provides selective directional earth fault protection for high impedance earthed networks that is for compensated unearthed and high resistance eart...

Page 554: ...ral point in the primary substation is not connected to earth However in unearthed networks fixed distributed compensation coils can also be used to compensate a part of the total capacitive earth fault current Typically the resulting compensation degree is less than 50 percent Thus unearthed networks with or without distributed compensation coils are generally referred to as unearthed networks in...

Page 555: ...tion requires that all three voltage channels are connected for calculating the re sidual voltage Setting VT connection must be Wye in that particular UTVTR Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing b...

Page 556: ...g or calculated derived from phase to earth voltages When the magnitude of U o 1 exceeds setting Voltage start value an earth fault is detected The GFC module reports the exceeded value to the Fault direction determination module and Operation logic The reporting is referenced as General Fault Criterion release The setting Voltage start value defines the basic sensitivity of MFADPSDE To avoid unse...

Page 557: ...otection sensitivity in terms of fault resistance value Stage 3 could be used to detect high ohmic earth faults and generate alarms for them To maximize the earth fault detection sensitivity of stage 3 Voltage start value should be selected based on the network s resonance curve see Figure 320 Such coordination of different protection stages enables Indication but no tripping of transient self ext...

Page 558: ...th harmonic components of residual current and zero sequence voltage The fundamental frequency admittance conductance and susceptance is calculated if the magnitude of a harmonic in residual current and zero sequence voltage is measurable by the relay Y I U G j B o o 0 1 0 1 0 1 1 1 3 Equation 88 Y0 1 Fundamental frequency neutral admittance phasor I0 1 Fundamental frequency zero sequence current ...

Page 559: ...n regardless of the fault type transient intermittent restriking permanent high or low ohmic the fault direction is calculated using a special filtering algorithm Cumulative Phasor Summing CPS technique This filtering method is advantageous during transient intermittent and restriking earth faults with dominantly non sinusoidal or transient content It is equally valid during continuous stable eart...

Page 560: ...y cause the sum admittance phasor to behave as in case of an unearthed network where directional phasors point in opposite directions in the faulty and healthy feeder The direction of MFADPSDE is defined with setting Directional mode as Forward or Reverse The operation characteristic is defined by a tilted operation sector as illustrated in Figure 322 The characteristic provides universal applicab...

Page 561: ...lt in the protected feeder without harmonics in the fault quantities when the network is compensated As no harmonic components are present the phase angle of the accumulated phasor is determined by the compensation degree of the network With a high degree of overcompensation the phasor turns towards the negative Im Yo axis as phasor 4 0 deg 90 deg 90 deg 45 deg Tilt angle Figure 322 Directional ch...

Page 562: ...he fault direction determination to possible fault direction change during the fault for example during manual fault location process a cyclic accumulation of sum admittance phasors is conducted The duration of this directional evaluation cycle is 1 2 Reset delay time minimum of 600 ms If the fault direction based on the cyclic phasor accumulation is opposite to the function direction output for R...

Page 563: ...f stabilized fundamental frequency susceptance estimate I G j B U I j I o stab ostab ostab baseres oCosstab oSinsta 1 1 1 1 b b 1 Equation 98 Io stab 1 Stabilized fundamental frequency residual current estimate which is obtained after conversion from the corresponding admittance value by multiplying it with the system nominal phase to earth voltage value Io Cosstab 1 Real part of stabilized fundam...

Page 564: ...ting Operating quantity Adaptive Directional mode Forward If the phase angle of accumulated sum admittance phasor is greater than 45 degrees current magnitude supervision is based on the amplitude of Io stab 1 which must exceed the set minimum operate current threshold If the phase angle of accumulated sum admittance phasor is below 45 degrees current magnitude supervision is based on the resistiv...

Page 565: ...ed networks during earth faults with rich harmonic content in residual quantities operation can be achieved without the parallel resistor of the centralized compensation coil When Operating quantity is set to Resistive the set minimum operate current threshold setting Min operate current is compared to the resistive component of Io stab 1 in the whole defined operate sector see Figure 324 90 deg 9...

Page 566: ...5 Operating quantity Amplitude and Directional mode Forward If the Adaptive or Resistive operating quantity is selected the setting Min operate current should be set to value pu p IRtot Equation 99 pu Min operate current IRtot Total resistive earth fault current of the network corresponding to the resistive current of the parallel resistor of the coil and the natural losses of the system typically...

Page 567: ...twork damping value I_DAMPING calculated by the coil controller can be used as a base for setting Min operate current If Operating quantity is set to Adaptive the setting value Min operate current is also applicable if the coil is disconnected and the network becomes unearthed In this case the current magnitude supervision is automatically based on the amplitude of Io stab 1 The selected setting v...

Page 568: ...tting without the function being reset depending on the drop off time set with the Reset delay time setting INTR_EF output is activated This indicates detection of restriking or intermittent earth fault in the network Transient detector affects the operation of MFADPSDE START and OPERATE outputs when operation mode is Intermittent EF For other operation modes General EF Alarming EF PEAK_IND and IN...

Page 569: ...compensated unearthed and high resistance earthed networks It detects earth faults regardless of their type transient intermittent or restriking permanent high or low ohmic and provides definite operate time for protection regardless of the fault type In General EF mode the operate timer is started in the following conditions Earth fault is detected by the GFC Fault direction equals Directional mo...

Page 570: ... view indicates the percentage ratio of the start situation and the set operating time If detection of temporary earth faults is not desired the activation of START output can be delayed with setting Start delay time The same setting can also be used to avoid restarting of the function during long lasting post fault oscillations if time constant of post fault oscillations is very long network loss...

Page 571: ...r restriking permanent high or low ohmic In Alarming EF mode the operate timer is started during the following conditions Earth fault is detected by the GFC Fault direction equals Directional mode setting Estimated stabilized fundamental frequency residual current Io stab 1 exceeds the set Min operate current level which is applied in current magnitude threshold supervision and which is further de...

Page 572: ... If detection of temporary earth faults is not desired the activation of START output can be delayed with setting Start delay time To keep the operate timer activated between current spikes during intermittent or restriking earth fault the Reset delay time should be set above the maximum expected time interval between fault spikes obtained at full resonance condition The recommended value is at le...

Page 573: ...y setting Reset delay time The OPERATE output is activated when Operate delay time has elapsed required number of transients has been detected earth fault is detected by the GFC fault direction matches the Directional mode setting and estimated stabilized fundamental frequency residual current exceeds set Minimum operate current setting Reset delay time starts to elapse from each detected transien...

Page 574: ...stor of the coil is not used for example in sub transmission networks In the Transient EF mode the fault direction is determined from the beginning of the fault and is held until earth fault is detected by GFC In the Transient EF mode the operate timer is started when the following conditions are met Earth fault is detected by the GFC Fault direction equals Directional mode setting and fault direc...

Page 575: ...lay time Operate delay time Io Uo Figure 331 Operation in Transient EF mode When operation mode Transient EF is selected Operating quantity should be set to Resistive and Min operate current to the minimum value Tilt angle should be 10 degrees especially if the residual current is measured with Holmgreen sum connection of phase current CTs Blocking logic There are three operation modes in the bloc...

Page 576: ...rogress output INPRO from DARREC to BLOCK input of MFADPSDE to allow faster reset of MFADPSDE during high speed auto reclosing cycle HSAR when setting Reset delay time equals or is higher than the dead time of high speed auto reclosing cycle HSAR 3 In case of a network with distributed coils but no centralized arc suppression coil at the primary substation unearthed network it is recommended to ad...

Page 577: ...e of MFADPSDE smaller than the connection duration time of the resistor If earth faults are only alarmed the external logic is not needed When the proposed logic is used and indication of transient earth faults is needed the START output from INTRPTEF can be used Timer If the detected fault direction is opposite to the set directional mode and GFC release is active BLK_EF output is activated once ...

Page 578: ... It can be applied for the earth fault protection of overhead lines and underground cables regardless of the earth fault type continuous transient or intermittent or the fault resistance value low or high ohmic MFADPSDE replaces traditional sensitive directional earth fault protection such as Iocos and transient earth fault protection such as Wischer principle combining the same functionality into...

Page 579: ... with several kilohms of fault resistance to be detected in a symmetrical system The achieved sensitivity is comparable with traditional fundamental frequency based methods such as the IoCos IoSin DEFxPTOC Watt Varmetric WPWDE and neutral admittance EFPADM MFADPSDE can detect faults with dominantly fundamental frequency content as well as transient intermittent or restriking earth faults MFADPSDE ...

Page 580: ... admit tance protection RESET BOOLEAN 0 False External trigger to re set direction calcula tio MFADPSDE Output signals Table 618 MFADPSDE Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start BLK_EF BOOLEAN Block signal for EF to indicate opposite direction peaks INTR_EF BOOLEAN Intermittent earth fault indi cation PEAK_IND BOOLEAN Current transient detection indication ...

Page 581: ...e 1 Intermittent EF 2 Transient EF 3 General EF 4 Alarming EF 3 General EF Operation criteria Table 622 MFADPSDE Non group settings Advanced Parameter Values Range Unit Step Default Description Peak counter limit 2 20 1 2 Peak counter limit for restriking EF Start delay time 30 60000 ms 1 30 Start delay time Reset delay time 0 60000 ms 1 500 Reset delay time Pol reversal 0 False 1 True 0 False Rot...

Page 582: ...0 identification IEC 60617 identification ANSI IEEE C37 2 device number Touch voltage based earth fault current protection IFPTOC IFPTOC 46SNQ 59N 4 2 10 2 Function block Figure 334 Function block 4 2 10 3 Functionality The touch voltage based earth fault current protection function IFPTOC provides selective earth fault protection for single phase earth faults in high impedance earthed networks th...

Page 583: ...afety regulations is questionable It should be noted that the time constant of coil tuning is much longer than requirements for protection operate time In modern networks high temporary detuning conditions are possible due to increase of use of underground cables which increase feeder total phase to earth capacitance enormously However operation of IFPTOC is not based on traditional residual quant...

Page 584: ...nt earth faults and for high current cross country earth faults Each of such fault condition can be tripped with individually defined operation criteria enabling high application flexibility and reliability 4 2 10 4 Analog channel configuration IFPTOC has four analog group inputs which must be properly configured Table 625 Analog inputs Input Description I3P Three phase currents IRES Residual curr...

Page 585: ...idity check Touch voltage estimation Faulted phase identifi cation Intermittent earth fault protection Cross country fault protection Fault resistance estimation OPERATE START PEAK_IND INTR_EF TRIGG_REC Recorded data EXT_RELEASE U_A U_B U_C U_AB U_BC U_CA I_A I_B I_C Uo Io VALID_EF XC_FLT Blocking logic OP_INTR ST_INTR OP_SOTF ST_SOTF ST_EF OP_EF ST_XC OP_XC Trip logic Switch onto fault protection...

Page 586: ... override earth fault validity check criterion i e earth fault current estimate is considered as valid when EXT_RELEASE is activated It is therefore mandatory that EXT_RELEASE is based on start of directional earth fault detection function such as MFADPSDE or DEFxPDEF The setting Voltage start value defines the basic sensitivity of the IFPTOC function in terms of fault resistance Fault detection s...

Page 587: ...g and compensation degree variations variation in detuning Activation of EF_IND output is determined to be the time instant when the earth fault is detected This information is needed as the IFPTOC utilizes delta calculation i e changes in phase currents due to earth fault For example the change of phase A current phasor due to earth fault can be written as Equation 102 Where tFLT is the time duri...

Page 588: ...on of operation of General Fault Criterion GFC module and the meaning of setting Revert time In case of secondary testing of IFPTOC function the pre fault time in the test file must be longer than 2xRevert time For example if Revert time 300 ms then pre fault time in the test file must be longer than 600 ms Indication of detected earth fault is available in Recorded data EF indication Fault curren...

Page 589: ...ent magnitude is proportional to scaling the fault current magnitude at zero fault resistance with the per unit value of residual voltage due to fault resistance Minimum fault current magnitude is always obtained at resonance when detuning Iv is zero in case Equation 104 can be written as Equation 108 At resonance fault current is only due to system resistive shunt losses i e due to network dampin...

Page 590: ...t change of phase C current phasor due to earth fault change of negative sequence current phasor due to earth fault Phase rotation operator cos 120 j sin 120 Applying the delta calculation i e change in phase currents due to earth fault removes the healthy state negative sequence component from earth fault current estimate which may exist due to the practical unbalances in load currents and capaci...

Page 591: ...can be enabled with setting Enable harmonics Enable Disable Fundamental frequency component is always included into fault current magnitude estimation even when setting Enable harmonics Disable When setting Enable harmonics Enable the included harmonics are if their magnitudes are sufficient for an accurate measurement 2nd 3rd 5th 7th and 9th Figure 338 Illustration of earth fault current estimate...

Page 592: ...gardless of actual fault resistance magnitude the earth fault current estimate matches the value that would be valid if the fault would be a galvanic one fault resistance equals zero Thanks to this feature the fault is always seen and treated as a galvanic fault regardless of possible fault resistance This functionality allows acceleration of protection operation speed during high er ohmic earth f...

Page 593: ...her ohmic earth fault RF 3000 ohm with setting Ena RF Compensation Disable Right hand column a higher ohmic earth fault RF 3000 ohm with setting Ena RF Compensation Enable Note that it is the effective earth fault current estimate which determines operation of IFPTOC Effective earth fault current includes the effect of user setting Reduction factor Effective earth fault current estimate Equation 1...

Page 594: ...ance is then not available in Monitored Recorded data but the monitored recorded current value is fault resistance compensated Validity check Validity of earth fault current estimate is defined with settings EF validity Op mode and EF validity Min Curr EF validity Op mode has three options Resistive Resistive Reactive and No Validity Validity of earth fault current estimate is based on evaluating ...

Page 595: ...ault current estimate EF validity Op mode Resistive Reactive is valid in compensated unearthed and in high resistance earthed systems In compensated systems this criterion is applicable unless the protected feeder is over compensated i e earth fault current produced by protected feeder is inductive In such case EF validity Op mode must be set to Resistive In case EF validity Op mode No validity th...

Page 596: ...to be suitable for most applications In resistance earthed networks EF validity Min Curr should be selected based on the value of earthing resistor Value must be smaller than the ampere value of earthing resistor To adapt the earth fault current validity determination to a possible fault direction change during the fault for example during manual fault location process a cyclic accumulation of adm...

Page 597: ... hazardous touch voltage at fault location the estimate of the effective earth potential rise is used Equation 119 Setting Reduction factor enables down scaling of the estimated earth potential rise which determines operation speed of IFPTOC In case Reduction factor 1 it is assumed that touch voltage equals 100 of earth potential rise In case Reduction factor 1 then it is assumed that touch voltag...

Page 598: ...condition It is important to set setting EF current Str Val according to required protection sensitivity OPERATE and OP_EF outputs are activated after operation timer has elapsed defined with setting DT stage Op time Reset timer is started if any of the above conditions for START is not anymore valid START and ST_EF outputs stay activated until the reset timer expires setting Reset delay time Afte...

Page 599: ...efinite time is illustrated in Figure 341 In the example setting EF current Str Val 0 04 In 4 A with primary 100 A and DT stage Op time 400 ms Reduction factor 1 0 IFPTOC starts when estimated fault current exceeds 4 A and operates after 400 ms if start conditions are met For illustrating possible operating speed requirements of protection limits of touch voltage and earth potential rise durations...

Page 600: ...ype Definite time Settings EF current Str Val 0 04 In 4A and DT stage Op time 400ms Reduction factor 1 0 Maximum earthing Ris 10ohm When Operating curve type Inverse time EN50522 is selected then Operate time is inverse time according to standard EN50522 Protection functions 1MRS759142 F 600 REX640 Technical Manual ...

Page 601: ...ns for START is not anymore valid START and ST_EF outputs stay activated until the reset timer expires setting Reset delay time After OPERATE output activation START ST_EF OPERATE and OP_EF outputs are reset immediately i e reset delay time is no longer valid During re striking intermittent earth faults the very high current transient may result to very fast operation times In case longer operatio...

Page 602: ...x 5 00 86 V REmax 172 V REmax 344 V REmax 10 00 85 V REmax 170 V REmax 340 V REmax 3 Minimum effective earth fault current magnitude considering the effect of setting Reduction factor which must be exceeded for the function to start is defined with setting EF current Str Val It is important to set this value according to required protection sensitivity 4 With IDMT stage Min Op Tm setting user can ...

Page 603: ...EN50522 Table 628 Comparison of operation times given in EN50522 with IFPTOC The theoretical operate time of IFPTOC has been calculated assuming CB delay Comp 0 s EN50522 Utp V EN50522 tf sec IFPTOC tf Theoretical sec 716 0 05 0 04 654 0 1 0 12 537 0 2 0 20 220 0 5 0 50 117 1 1 00 96 2 1 59 86 5 5 02 85 10 8 48 Example 2a Inverse time operation of IFPTOC when Operation principle EF current based a...

Page 604: ...rve type Inverse time EN50522 is illustrated in Figure 344 Start value for operation is set to be 0 04 In 4 A IFPTOC is set to have minimum operate time 100 ms and maximum operate time of 5000 ms Setting UTp multiplier is 2 0 and setting Maximum earthing Ris is 10 ohms Reduction factor 1 0 For illustrating the operating speed requirement of protection limits of earth potential rise durations defin...

Page 605: ...urve type Inverse time EN50522 is illustrated in Figure 345 Start value for operation is set to be 0 06 In 6 A IFPTOC is set to have minimum operate time 100 ms and maximum operate time of 5000 ms Setting UTp multiplier is 4 0 and setting Maximum earthing Ris is 10 ohms Reduction factor 1 0 For illustrating the operating speed requirement of protection limits of earth potential rise durations defi...

Page 606: ... 0 Maximum earthing Ris 10 ohms EF current Str Val 0 06 In 6 A IDMT stage Min Op Tm 100 ms and IDMT stage Max Op Tm 5000 ms Reduction factor 1 0 Characteristics are according to standard EN50522 When Operating curve type Inverse time IEEE80 is selected then Operate time is inverse time according to standard IEEE80 Protection functions 1MRS759142 F 606 REX640 Technical Manual ...

Page 607: ...t timer is started if any of the above conditions for START is not anymore valid START and ST_EF outputs stay activated until the reset timer expires setting Reset delay time After OPERATE output activation START ST_EF OPERATE and OP_EF outputs are reset immediately i e reset delay time is no longer valid During re striking intermittent earth faults the very high current transient may result to ve...

Page 608: ...rresponding earth fault current requirements When Operating curve type Inverse time IEEE80 is selected then the protection operate time as a function of estimated effective earth fault current taking into account the effect of settings Reduction factor and Enable harmonics is according to equation below Equation 125 Example numerical values of the permissible touch voltage UTp converted into corre...

Page 609: ...ly disconnected within time t sec a 750V t b 2000V t c 3000V t d 500V t e1 750V t e2 1000V t The regulations of Table 630 are implemented into IFPTOC In case Operation principle EF current based setting Maximum earthing Ris is used to convert the highest allowed earth potential risevalues into corresponding earth fault current values Setting IEEE multiplier is set to equal the highest allowed volt...

Page 610: ...rinciple EF current based and Operating curve type Inverse time IEEE80 is selected Setting Maximum earthing Ris is needed to scale the touch voltage and earth potential rise requirements defined in standard IEEE80 into corresponding earth fault current requirements Setting Reduction factor considers the fact that only part of the earth fault current IF will flow back through remote earth and intro...

Page 611: ...000 ms Reduction factor 1 0 Characteristics are according to standard IEEE80 Principle based on touch voltage estimate The operation of IFPTOC based on touch voltage estimate is described next In case Operation principle Touch voltage based then operation is based on the estimated touch voltage magnitude according to Equation 119 The harmonic content of touch voltage can be included into estimate ...

Page 612: ...y time is no longer valid During re striking intermittent earth faults in case operation should be based preferably on counted number of transients then setting Reset delay time should be set to low value say 20 40 ms thus definite operation is ineffective during re striking intermittent earth faults Dedicated intermittent earth fault protection functionality based on counted number of transients ...

Page 613: ...ng Maximum earthing Ris must be always set in case Operation principle Touch voltage based and Operating curve type Definite time is selected Setting Maximum earthing Ris is needed to scale the estimated earth fault current value into corresponding touch voltage or earth potential rise value When Operating curve type Inverse time EN50522 is selected then Operate time is inverse time according to s...

Page 614: ...lid START and ST_EF outputs stay activated until the reset timer expires setting Reset delay time After OPERATE output activation START ST_EF OPERATE and OP_EF outputs are reset immediately i e reset delay time is no longer valid During re striking intermittent earth faults the very high current transient may result to very fast operation times In case longer operation during re striking intermitt...

Page 615: ...ting user can define minimum allowed operate time for IFPTOC i e this is the minimum allowed operate time of IFPTOC 5 With IDMT stage Max Op Tm setting user can define maximum allowed operate time for IFPTOC i e this is the maximum allowed operate time of IFPTOC although IDMT timer would define slower operate time Parameter defining maximum earthing resistance setting Maximum earthing Ris must be ...

Page 616: ...permissible estimated touch voltage as illustrated in Figure 350 Figure 351 and Figure 352 Consider next three examples with Operating curve type Inverse time EN50522 Example 5a Inverse time operation of IFPTOC when Operation principle Touch voltage based Operating curve type Inverse time EN50522 and setting UTp multiplier 1 0 is illustrated in Figure 350 Start value for operation is set to be 20 ...

Page 617: ...iplier 2 0 is illustrated in Figure 351 Start value for operation is set to be 40 V setting Touch Vol Str Val IFPTOC is set to have minimum operate time 100 ms and maximum operate time of 5000 ms settings IDMT stage Min Op Tm IDMT stage Max Op Tm Maximum earthing resistance value encountered in the protected feeder is set to be 10 ohms setting Maximum earthing Ris and Reduction factor 1 For illust...

Page 618: ...ier 4 0 is illustrated in Figure 352 Start value for operation is set to be 60 V setting Touch Vol Str Val IFPTOC is set to have minimum operate time 100 ms and maximum operate time of 5000 ms settings IDMT stage Min Op Tm IDMT stage Max Op Tm Maximum earthing resistance value encountered in the protected feeder is set to be 10 ohms setting Maximum earthing Ris and Reduction factor 1 For illustrat...

Page 619: ... curve type Inverse time EN50522 and UTp multiplier 4 0 Characteristics are according to standard EN50522 Maximum earthing Ris 10 ohm When Operating curve type Inverse time IEEE80 is selected then Operate time is inverse time according to standard IEEE80 1MRS759142 F Protection functions REX640 Technical Manual 619 ...

Page 620: ...RT is not anymore valid START and ST_EF outputs stay activated until the reset timer expires setting Reset delay time After OPERATE output activation START ST_EF OPERATE and OP_EF outputs are reset immediately i e reset delay time is no longer valid During re striking intermittent earth faults the very high current transient may result to very fast operation times In case longer operation during r...

Page 621: ...itude can be adjusted For body weight of 70 kg Cs 1 ρs ρ 0 Ω m then IEEE multiplier equals 157 0 In IFPTOC the protection operate time t as a function of estimated touch voltage according to standard IEEE80 follows equation below Equation 131 Example numerical values of the permissible touch voltage UTp as a function of the fault duration tf according to standard IEEE80 are shown in Table 633 Valu...

Page 622: ...ue for example for group d IEEE multiplier 500 It is important to note that 1 Minimum effective touch voltage magnitude considering the effect of Reduction factor which must be exceeded for the function to start is defined with setting Touch Vol Str Val It is important to set setting Touch Vol Str Val according to required protection sensitivity 2 With IDMT stage Min Op Tm setting user can define ...

Page 623: ...erse time IEEE80 and setting IEEE multiplier 500 is illustrated in Figure 354 Start value for operation is set to be 20 V setting Touch Vol Str Val IFPTOC is set to have minimum operate time 100 ms and maximum operate time of 5000 ms settings IDMT stage Min Op Tm IDMT stage Max Op Tm Maximum earthing resistance value encountered in the protected feeder is set to be 10 ohms setting Maximum earthing...

Page 624: ...le phase earth fault introduces over voltages in the healthy phases Such over voltages may initiate another single phase earth fault in another phase and location in a galvanically connected network Such fault condition is commonly known as cross country fault which is a two phase short circuit through earth with high earth fault current Cross country fault must be therefore quickly disconnected i...

Page 625: ...criterion requires that residual current exceeds a value which is higher than maximum single phase earth fault current of the network and the 2nd criterion monitors voltage dip in any of the phase to phase voltages Residual over current criterion Monitoring of the magnitude of calculated residual current Io and comparing it to setting XC stage A Str Val during a detected earth fault Equation 132 C...

Page 626: ...mittance corresponding to the maximum of the set earthing resistance values of other feeders in the substation Xk Sum of short circuit reactances of the incoming HV network and main transformer referred to MV side Rk Sum of short circuit resistances of the incoming HV network and main transformer referred to MV side Example 1 Un_PE 11 547 kV Maximum earthing Ris 15 ohm Maximum earthing Ris_i 10 oh...

Page 627: ...is the nominal phase to phase voltage In case all three phase to phase voltages UAB UBC and UCA are under setting for XC stage PP V Val such condition is considered as permanent three phase under voltage condition not a cross country fault Figure 356 Illustration of behavior of residual phase to earth and phase to phase voltages during an evolvement of single phase earth fault into cross country f...

Page 628: ...pply voltage the setting XC stage PP V Val can be selected 0 9xUn_PP 18 0 kV In this way unnecessary activations of phase to phase undervoltage condition can be prevented Figure 357 illustrates fault current magnitude according to Equation 134 and phase to phase voltage magnitude according to Equation 136 during a cross country fault as a function of fault resistance Note that fault resistance is ...

Page 629: ...etting value XC stage PP V Val is given in per unit format with system nominal phase to phase value as reference Fulfilment of either Equation 132 or Equation 135 declares cross county fault detection condition in the network The cross country fault is indicated by activating the XC_FLT output During detected cross country fault the EF current based or Touch voltage based operation of IFPTOC is bl...

Page 630: ...tr Val XC stage PP V Val XC stage Op time and Reset delay time Intermittent earth fault protection Operation time requirement of earth fault protection in safety standards assumes continuous flow of fault current In case of resonant earthed network earth faults are often re striking i e fault arc is not continuous but intermittent During re striking intermittent earth faults the very high but narr...

Page 631: ...hes the Intr EF counter Lim setting INTR_EF output is activated Activation of INTR_EF output indicates detection of a restriking or intermittent earth fault in the protected feeder Figure 358 Illustration of operation of intermittent earth fault module Setting Intr EF counter Lim 3 When a required number of intermittent earth fault transients set with the Intr EF counter Lim setting are detected w...

Page 632: ...lts the very high current transient may result to very fast operation times in case operation principle is based on earth fault current or touch voltage estimate In case longer and more deterministic operation during re striking intermittent earth faults is preferred the operation can be based on counted number of transients instead of IDMT operation In transient counter based operation the settin...

Page 633: ...applied in the protection configuration ALL instances of IFPTOC requires SOTF module functionality to be enabled to provide selective operation during an SOTF condition SOTF condition is declared if an earth fault is detected EF_IND TRUE within set SOTF Cond duration milliseconds from breaker close command input CB_CL_CMD is activated Indication of detected SOTF condition is declared by activation...

Page 634: ...rmittent earth fault setting SOTF reset time Recommended setting value is between 300 500 ms Applicable settings for the SOTF module are Enable SOTF mode SOTF Cond duration SOTF operate time and SOTF reset time Note that setting CB Delay comp circuit breaker delay compensation is not applicable in definite time operation but it must be taken into account in setting SOTF operate time Faulted phase ...

Page 635: ...accurate Trip logic Protection function IFPTOC supports both tripping and alarming earth fault handling defined with setting Operation mode Alarming EF or Tripping EF With Operation mode Alarming EF OPERATE and corresponding OP_EF OP_XC OP_SOTF OP_INTR outputs are not activated Operation mode Alarming EF is applicable in networks where due to low touch voltages tripping of earth fault is not requi...

Page 636: ...t module Switch onto fault SOTF module Intermittent earth fault module Binary 0 or 1 0 not started not op erated 1 started operated 0 or 1 0 or 1 0 or 1 0 or 1 Started Operated timers integer Timer1 20 Timer2 21 Timer3 22 Timer4 23 Numerical example If both Touch voltage fault current estimation module timer 1 and intermittent timer 8 have been started but only Touch voltage estimation module time...

Page 637: ...AResImag mag f Non qualified Harmon Non qualified harmonics ST IF1RFRCx NonQualH stVal EF indication Non directional earth fault detection ST IF1RFRCx EFDet stVal Valid EF detection Valid EF detection in protected feeder ST IF1RFRCx EFDetVald stVal XC fault detection Cross country fault detection ST IF1RFRCx XcnDet stVal Time left to operate Time left to operate sec MX IF1RFRCx TmOpEst mag f Inter...

Page 638: ...REC BOOLEAN 0 False External recorded da ta triggering There are two recorded data banks available IFPTOC Output signals Table 638 IFPTOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start ST_EF BOOLEAN Start signal according to estimated fault current or touch voltage according to the standards ST_XC BOOLEAN Start signal according to cross country stage earth fault m...

Page 639: ...TOC Group settings Basic Parameter Values Range Unit Step Default Description Voltage start value 0 01 1 00 xUn 0 01 0 20 Start value for neu tral point voltage Uo Note that Un means phase to earth nominal volt age EF current Str Val 0 005 1 000 xIn 0 001 0 010 Earth fault current threshold for DT stage or IDMT stage Note that In means phase nomi nal current Touch Vol Str Val 10 0 2900 0 V 0 1 80 ...

Page 640: ...0 Maximum earthing resistance encoun tered in the protec ted feeder in pri mary ohms accord ing to standard EN50522 IEEE80 IEEE multiplier 50 0 5000 0 0 1 157 0 Multiplier accord ing to standard IEEE80 XC stage A Str Val 0 10 5 00 xIn 0 01 1 00 Current threshold for cross country fault module Note that In means phase nominal cur rent XC stage PP V Val 0 01 1 00 xUn 0 01 0 90 Phase to phase voltage...

Page 641: ...ping EF 2 Tripping EF Operation criteria Enable XC Op mode 1 on 5 off 1 on Enable cross coun try fault tripping functionality Reset delay time 0 6000 ms 10 20 Reset delay time Ena Intermit EF mode 1 on 5 off 1 on Enable intermittent earth fault module Enable SOTF mode 1 on 5 off 1 on Enable Switch On To Fault logic mod ule SOTF Cond dura tion 100 16000 ms 10 2000 Switch On To Fault module duration...

Page 642: ...touch voltage pri mary volts rms incl harmonics RF FLOAT32 0 0 20000 0 ohm Fault point resistance in primary ohms FAULT_PHASE Enum 5 No fault 4 ABCG Fault 3 CAG Fault 2 BCG Fault 1 ABG Fault 1 AG Fault 2 BG Fault 3 CG Fault 4 AB Fault 5 BC Fault 6 CA Fault 7 ABC Fault Faulted phase TR_RIS_COMP FLOAT32 6000 0 6000 0 A Magnitude of transi ent real part of resid ual current in primary amperes fundame...

Page 643: ...currents 10 x In Start time 1 Typically 30 ms Reset time 30 ms Reset ratio Typically 0 96 Retardation time 50 ms Operate time accuracy 1 0 of the set value or 20 ms DT 3 of the theoretical value or 40 ms IDMT 4 3 Differential protection 4 3 1 Line differential protection with in zone power transformer LNPLDF ANSI 87L 4 3 1 1 Identification Function description IEC 61850 identification IEC 60617 id...

Page 644: ...ere faults with a high differential current regardless of their harmonics The operating time characteristic for the low stage can be selected to be either definite time DT or inverse definite time IDMT The direct inter trip ensures both ends are always operated even without local criteria 4 3 1 4 Analog channel configuration LNPLDF has one analog group input which must be properly configured Table...

Page 645: ...ule diagram I_LOC_x stands for current of the local end and I_REM_x for phase currents of the remote ends Stabilized low stage In the stabilized low stage the higher the load current is the higher the differential current required for tripping is This happens on normal operation or during external faults When an internal fault occurs the currents on both sides of the protected object flow towards ...

Page 646: ... OPERATION Slope section 3 Slope section 2 End section 1 End section 2 PROT_ACTIVE from Fail safe function BLKD2H_LOC from Inrush detector BLKD2H_REM from Inrush detector Figure 362 Operation logic of the stabilized low stage The stabilization affects the operation of the function Figure 363 Operating characteristics of the protection LS stands for the low stage and HS for the high stage The slope...

Page 647: ...ased local blocking is selected into use with the Restraint mode parameter The blocking for the low stage on the local end is issued when the second harmonic blocking is selected and the inrush is detected The inrush detector calculates the ratio of the second harmonic current I_2H_LOC_A and the fundamental frequency current I_1H_LOC_A If the line differential protection is used in normal mode Win...

Page 648: ...tion INCOMING INCOMING PROTECTED ZONE RED 615 RED 615 Figure 365 Basic protection principle The differential current I I d of the protection relay is obtained on both ends with the formula I I I d LOC REM Equation 142 The stabilizing current I bias I b of the protection relay is obtained on both ends with the formula I I I b LOC REM 2 Equation 143 Depending on the location of the star points of th...

Page 649: ...66 Example of CT ratio correction setting calculation in line differential application The settings for CT ratio Corrections for protection relay A and protection relay B are CT ratio Correction A 800 A 400 A 2 000 CT ratio Correction B 400 A 400 A 1 000 The CT secondary current often differs from the rated current at the rated load of the power transformer The CT transforming ratio can be correct...

Page 650: ..._B 5 MVA 1 732 10 5 kV 274 9 A So the settings for CT ratio corrections at HV A and LV B side are CT ratio correction A 200 A 144 3 A 1 386 CT ratio correction B 300 A 274 9 A 1 091 CT connections The connections of the primary current transformers are designated as Type 1 and Type 2 If the positive directions of the winding 1 and winding 2 protection relay currents are opposite the CT connection ...

Page 651: ...Figure 368 Connection example of current transformers of Type 1 1MRS759142 F Protection functions REX640 Technical Manual 651 ...

Page 652: ...Figure 369 Connection example of current transformers of Type 1 Protection functions 1MRS759142 F 652 REX640 Technical Manual ...

Page 653: ...Figure 370 Connection example of current transformers of Type 2 1MRS759142 F Protection functions REX640 Technical Manual 653 ...

Page 654: ...tion Winding 1 type Winding 2 type and Clock number settings Thus no interposing CTs are needed if there is only a power transformer inside the protected zone The matching is based on phase shifting and a numerical delta connection in the protection relay If the neutral of a star connected power transformer is earthed any earth fault in the network is perceived by the protection relay as a differe...

Page 655: ... yn d z zn When the vector group matching is Yy0 and the CT connection type is according to Type 2 the phase angle of the phase currents connected to the protection relay does not change When the vector group matching is Yy6 the phase currents are on one side turned 180 in the protection relay Example 1 vector group matching of an YNd11 connected power transformer on winding 1 CT connection type a...

Page 656: ...tor group matching Vector group of the transformer Winding 1 type Winding 2 type Phase shift Zero sequence current elimination Yy0 Y y 0 Not needed YNy0 YN y 0 HV side YNyn0 YN yn 0 HV LV side Yyn0 Y yn 0 LV side Yy2 Y y 2 Not needed YNy2 YN y 2 Automatic YNyn2 YN yn 2 Automatic Yyn2 Y yn 2 Automatic Yy4 Y y 4 Not needed YNy4 YN y 4 Automatic YNyn4 YN yn 4 Automatic Yyn4 Y yn 4 Automatic Yy6 Y y 6...

Page 657: ...4 Not needed Dd6 D d 6 Not needed Dd8 D d 8 Not needed Dd10 D d 10 Not needed Dy1 D y 1 Not needed Dyn1 D yn 1 Automatic Dy5 D y 5 Not needed Dyn5 D yn 5 Automatic Dy7 D y 7 Not needed Dyn7 D yn 7 Automatic Dy11 D y 11 Not needed Dyn11 D yn 11 Automatic Yz1 Y z 1 Not needed YNz1 YN z 1 Automatic YNzn1 YN zn 1 LV side Yzn1 Y zn 1 Automatic Yz5 Y z 5 Not needed YNz5 YN z 5 Automatic YNzn5 YN zn 5 LV...

Page 658: ... 7 Automatic ZNyn7 ZN yn 7 HV side ZNy7 ZN y 7 Automatic Zy11 Z y 11 Not needed Zyn11 Z yn 11 Automatic ZNyn11 ZN yn 11 HV side ZNy11 ZN y 11 Automatic Dz0 D z 0 Not needed Dzn0 D zn 0 LV side Dz2 D z 2 Not needed Dzn2 D zn 2 Automatic Dz4 D z 4 Not needed Dzn4 D zn 4 Automatic Dz6 D z 6 Not needed Dzn6 D zn 6 LV side Dz8 D z 8 Not needed Dzn8 D zn 8 Automatic Dz10 D z 10 Not needed Dzn10 D zn 10 ...

Page 659: ...zn 4 Automatic Zz6 Z z 6 Not needed ZNz6 ZN z 6 HV side ZNzn6 ZN zn 6 HV LV side Zzn6 Z zn 6 LV side Zz8 Z z 8 Not needed ZNz8 ZN z 8 Automatic ZNzn8 ZN zn 8 Automatic Zzn8 Z zn 8 Automatic Zz10 Z z 10 Not needed ZNz10 ZN z 10 Automatic ZNzn10 ZN zn 10 Automatic Zzn10 Z zn 10 Automatic Zero sequence component elimination If Clock number is Clk Num 2 Clk Num 4 Clk Num 8 or Clk Num 10 the vector gro...

Page 660: ...lta connected side of the Ynd power transformer in the area to be protected In this case the vector group matching is normally made on the side of the star connection On the side of the delta connection the elimination of the zero sequence component has to be eliminated by using the Zro A elimination parameter By using the Zro A elimination parameter the zero sequence component of the local phase ...

Page 661: ... timer has reached the value set with the Operate delay time in the DT mode or the maximum value defined by the inverse time curve the OPR_LS_LOC output is activated When the operation mode is according to IDMT Low operate value is used as reference value Start value in the IDMT equations presented in the Standard inverse time characteristics section A timer reset state is activated when a drop of...

Page 662: ... when a fault is detected Both start and operate signals are sent to the remote end via communication The direct intertripping of the line differential protection is included into LNPLDF The OPERATE output combines the operate signals from both stages local and remote so that it can be used for the direct inter trip signal locally Protection functions 1MRS759142 F 662 REX640 Technical Manual ...

Page 663: ...ing the function BLOCK and BLOCK_LS The difference between these inputs is that BLOCK_LS when TRUE blocks only the stabilized low stage leaving the instantaneous high stage operative BLOCK when TRUE blocks both stages and also the PRO_ACTIVE output is updated according to the BLOCK input status as described in the Fail safe function chapter The BLOCK and BLOCK_LS input statuses affect only the beh...

Page 664: ...ted current samples back with the shifted phase The current samples that are sent to the remote protection relay are scaled with the CT ratio correction setting The operation of both stages stabilized low or instantaneous high are blocked and also the direct inter trip functionality is blocked both receive and send in the protection relay where the test mode is active The remote end line different...

Page 665: ...when this test mode is used Required material for testing the protection relay Calculated settings Terminal diagram Circuit diagrams Technical and application manuals of the protection relay Single of three phase secondary current source Single of three phase primary current source Timer with start and stop interfaces Auxiliary voltage source for the protection relays PC with related software a We...

Page 666: ...tection relay and all the connected circuits are to be de energized during the check up Checking of CT circuits Check that the wiring is in strict accordance with the supplied connection diagram The CTs must be connected in accordance with the terminal diagram provided with the protection relay both with regards to phases and polarity The following tests are recommended for every primary CT or CT ...

Page 667: ... sure that all signals are connected correctly If there is no need to test a particular input the corresponding wiring can be disconnected from the terminal of the protection relay during testing Check all the connected signals so that both input voltage level and polarity are in accordance with the protection relay specifications However attention must be paid to the electrical safety instruction...

Page 668: ... power supply module of the protection relay AIM1001 X2 1 2 3 4 5 6 REX640 Breakable terminal blocks Test device 1 2 5 7 6 TIMER STOP A P1 P2 S1 S2 8 PSM100x X1 PSM100x X2 Figure 377 Example of connections to test the line differential protection relay Secondary current injection There are two alternative modes to check the operation of a line differential protection relay These are not exclusive ...

Page 669: ...s equal for phases L2 and L3 Verifying the settings 1 Block the unwanted trip signals from the protection relay units involved 2 Inject a current in phase L1 and increase the current until the function operates for phase L1 The injected operate current corresponds to the set Low operate value The monitored values for ID_A should be equal to the injected current 3 Repeat point 2 by current injectio...

Page 670: ...arthed networks compensated impedance earthed networks and solidly earthed networks In a typical network configuration where the line differential protection scheme is applied the protected zone that is the line or cable is fed from two directions Communication INCOMING INCOMING PROTECTED ZONE RED 615 RED 615 Figure 379 Line protection with phase segregated line differential with in zone transform...

Page 671: ...When the communication supervision function detects a failure in the communication between the protective units the safe operation of the line is still guaranteed by blocking the line differential protection and unblocking the over current functions When a communication failure is detected the protection communication supervision function issues block for the LNPLDF line differential protection an...

Page 672: ...TOC PHIPTOC PHHPTOC 2 LNPLDF PCSITPC BLOCK UNBLOCK UNBLOCK PHHPTOC 1 PHLPTOC PHLPTOC PHHPTOC 1 PHIPTOC RED 615 RED 615 RED 615 Figure 381 Protection communication supervision detects failures on communication Protection functions 1MRS759142 F 672 REX640 Technical Manual ...

Page 673: ... 300 A 209 9 A CT ratio correction LV 1 299 1500 A 1154 7 A Small power transformers in a tap With a relatively small power transformer in a line tap the line differential protection can be applied without the need of current measurement from the tap In such cases the line differential function is time delayed for low differential currents below the high set limit and LNPLDF coordinates with the d...

Page 674: ...ts when the fault is located on the line Z 10 33kV A kV kVA IF 23 96 10 0 33 3 500 1 1 400A 1 400A 1 500kVA Inst Time delayed 24 24 0 1A 400 23 96 I A A A RED 615 RED 615 Figure 384 Influence of the short circuit current at LV side of the tapped transformer to the differential current Detection of the inrush current during transformer start up When the line is energized the transformer magnetizati...

Page 675: ...e 385 Blocking of line differential functions during detected transformer start up current If the protection stage is allowed to start during the inrush situation the time delay can be selected so that the stabilized stage does not operate in the inrush situation 4 3 1 8 Signals LNPLDF Input signals Table 647 LNPLDF Input signals Name Type Default Description I3P SIGNAL Three phase currents BLOCK ...

Page 676: ...OLEAN Operate instantaneous stage remote BLKD2H_LOC BOOLEAN Restraint due 2nd harmonics detected local BLKD2H_REM BOOLEAN Restraint due 2nd harmonics detected remote PRO_ACTIVE BOOLEAN Status of the protection true when function is operative 4 3 1 9 LNPLDF Settings Table 649 LNPLDF Group settings Basic Parameter Values Range Unit Step Default Description Low operate value 10 200 Ir 1 10 Basic sett...

Page 677: ...delay curve for sta bilized stage Operate delay time 45 200000 ms 1 45 Operate delay time for stabilized stage Table 650 LNPLDF Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 4 test blocked 5 off 1 on Operation mode of the function Winding selection 1 Not in use 2 Winding 1 3 Winding 2 1 Not in use IED location re spect to transform er HV Winding 1 sid...

Page 678: ...2 LNPLDF Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time I_AMPL_LOC_A FLOAT32 0 00 40 00 xIr Local phase A ampli tude after correction I_AMPL_LOC_B FLOAT32 0 00 40 00 xIr Local phase B ampli tude after correction I_AMPL_LOC_C FLOAT32 0 00 40 00 xIr Local phase C ampli tude after correction I_AMPL_REM_A FLOAT32 0 00 40 00 xIr Re...

Page 679: ...de phase IL1 IL2 bias 1 FLOAT32 0 00 80 00 Measured bias current amplitude phase IL2 IL3 bias 1 FLOAT32 0 00 80 00 Measured bias current amplitude phase IL3 4 3 1 11 Technical data Table 653 LNPLDF Technical data Characteristics Value Operation accuracy 1 Depending on the frequency of the measured current fn 2 Hz Low stage 2 5 of the set value High stage 2 5 of the set value High stage operate tim...

Page 680: ...3 2 3 Functionality The stabilized and instantaneous differential protection for two winding transformers function TR2PTDF is designed to protect two winding transformers and generator transformer blocks TR2PTDF includes low biased and high instantaneous stages The biased low stage provides a fast clearance of faults while remaining stable with high currents passing through the protected zone incr...

Page 681: ...s See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the prote...

Page 682: ...tes phase wise on a difference of incoming and outgoing currents The positive direction of the currents is towards the protected object Winding 1 usually HV Winding 2 usually LV 1 W I 2 W I Figure 388 Positive direction of the currents I I I d W W 1 2 Equation 157 In a normal situation no fault occurs in the area protected by TR2PTDF Then the currents IW1 and IW 2 are equal and the differential cu...

Page 683: ...e biased stage are inhibited Transformer vector group matching The phase difference of the winding 1 and winding 2 currents that is caused by the vector group of the power transformer is numerically compensated The matching of the phase difference is based on the phase shifting and the numerical delta connection inside the protection relay The Winding 1 type parameter determines the connection on ...

Page 684: ...at the same time Zero sequence component elimination If Clock number is Clk Num 2 Clk Num 4 Clk Num 8 or Clk Num 10 the vector group matching is always done on both winding 1 and winding 2 The combination results in the correct compensation In this case the zero sequence component is always removed from both sides automatically The Zro A elimination parameter cannot change this If Clock number is ...

Page 685: ... position of the tap changer used for voltage control can be compensated and the position information is provided for the protection function through the tap position indication function TPOSYLTC Typically the tap changer is located within the high voltage winding that is winding 1 of the power transformer The Tapped winding parameter specifies whether the tap changer is connected to the high volt...

Page 686: ...sitized with the total range of the tap position correction The new acting low operate value is Desensitized Low operate value Lowoperatevalue ABS MaxWi n nding tap Minwinding tap Stepof tap Equation 162 Second harmonic blocking The transformer magnetizing inrush currents occur when energizing the transformer after a period of de energization The inrush current can be many times the rated current ...

Page 687: ...nabled through the Restraint mode parameter Using separate blocking for the individual phases and weighted averages calculated for the separate phases provides a blocking scheme that is stable at the connection inrush currents If the peak value of the differential current is very high that is I r 12 In the limit for the second harmonic blocking is desensitized in the phase in question by increasin...

Page 688: ...The biased low stage can always be blocked with waveform blocking The stage can not be disabled with the Restraint mode parameter This algorithm has two parts The first part is intended for external faults while the second is intended for inrush situations The algorithm has criteria for a low current period during inrush where also the differential current not derivative is checked Biased low stag...

Page 689: ...ected area the high currents fed by the transformer in motor start up or the transformer inrush situations Therefore the operation of the differential protection is biased in respect to the load current In biased differential protection the higher the differential current required for the protection to operate the higher the load current The operating characteristic of the biased low stage is dete...

Page 690: ...iased low stage is blocked by the fifth harmonic blocking functionality the BLKD5H output is activated Correspondingly when the operation of the biased low stage is blocked by the waveform blocking functionality the BLKDWAV output is activated according to the phase information When required the operate outputs of the biased low stage can be blocked by the BLK_OPR_LS or BLOCK external control sign...

Page 691: ...of the transformer increases as well In general the magnetic flux density of the transformer is rather high at rated voltage and a rise in voltage by a few percent causes the magnetizing current to increase by tens of percent This should be considered in Low operate value In section 2 where End section 1 Ib In End section 2 is called the influence area of Slope section 2 In this section variations...

Page 692: ...ntaneous stage operates and the output OPR_HS is activated when the amplitude of the fundamental frequency component of the differential current exceeds the set High operate value or when the instantaneous value of the differential current exceeds 2 5 times the value of High operate value The factor 2 5 1 8 2 is due to the maximum asymmetric short circuit current If the biasing current is small co...

Page 693: ...high stage Reset of the blocking signals de block All three blocking signals that is waveform and second and fifth harmonic have a counter which holds the blocking on for a certain time after the blocking conditions have ceased to be fulfilled The deblocking takes place when those counters have elapsed This is a normal case of deblocking The blocking signals can be reset immediately if a very high...

Page 694: ...aults in windings and terminals are normally detected by the differential protection If enough turns are short circuited the interturn faults which are flashovers between the conductors within the same physical winding are also detected The interturn faults are the most difficult transformer winding faults to detect with electrical protections A small interturn fault including a few turns results ...

Page 695: ...gure 396 Differential protection of a generator transformer block and short cable line TR2PTDF can also be used in three winding transformer applications or two winding transformer applications with two output feeders On the double feeder side of the power transformer the current of the two CTs per phase must be summed by connecting the two CTs of each phase in parallel Generally this requires the...

Page 696: ...rmer currents to a two winding protection relay The fundamental frequency component is numerically filtered with a Fourier filter DFT The filter suppresses frequencies other than the set fundamental frequency and therefore the protection relay is not adapted for measuring the output of the frequency converter that is TR2PTDF is not suited for protecting of a power transformer or motor fed by a fre...

Page 697: ...Figure 398 Protection of the power transformer feeding the frequency converter 1MRS759142 F Protection functions REX640 Technical Manual 697 ...

Page 698: ...e Next the settings for the CT ratio correction can be calculated CT ratio correction I I n nT 1 Equation 166 I 1n nominal primary current of the CT After the CT ratio correction the measured currents and corresponding setting values of TR2PTDF are expressed in multiples of the rated power transformer current I r xI r or percentage value of I r I r The rated input current 1A or 5A of the relay doe...

Page 699: ...The matching is based on phase shifting and a numerical delta connection in the protection relay If the neutral of a star connected power transformer is earthed any earth fault in the network is perceived by the protection relay as a differential current The elimination of the zero sequence component can be selected for that winding by setting the Zro A elimination parameter Table 655 TR2PTDF sett...

Page 700: ...0 YN y Clk Num 10 Not needed YNyn10 YN yn Clk Num 10 Not needed Yyn10 Y yn Clk Num 10 Not needed Yd1 Y d Clk Num 1 Not needed YNd1 YN d Clk Num 1 Not needed Yd5 Y d Clk Num 5 Not needed YNd5 YN d Clk Num 5 Not needed Yd7 Y d Clk Num 7 Not needed YNd7 YN d Clk Num 7 Not needed Yd11 Y d Clk Num 11 Not needed YNd11 YN d Clk Num 11 Not needed Dd0 D d Clk Num 0 Not needed Dd2 D d Clk Num 2 Not needed D...

Page 701: ...lk Num 11 Not needed YNz11 YN z Clk Num 11 Not needed YNzn11 YN zn Clk Num 11 LV side Yzn11 Y zn Clk Num 11 Not needed Zy1 Z y Clk Num 1 Not needed Zyn1 Z yn Clk Num 1 Not needed ZNyn1 ZN yn Clk Num 1 HV side ZNy1 ZN y Clk Num 1 Not needed Zy5 Z y Clk Num 5 Not needed Zyn5 Z yn Clk Num 5 Not needed ZNyn5 ZN yn Clk Num 5 HV side ZNy5 ZN y Clk Num 5 Not needed Zy7 Z y Clk Num 7 Not needed Zyn7 Z yn ...

Page 702: ...Clk Num 4 Not needed Zd6 Z d Clk Num 6 Not needed ZNd6 ZN d Clk Num 6 HV side Zd8 Z d Clk Num 8 Not needed ZNd8 ZN d Clk Num 8 Not needed Zd10 Z d Clk Num 10 Not needed ZNd10 ZN d Clk Num 10 Not needed Zz0 Z z Clk Num 0 Not needed ZNz0 ZN z Clk Num 0 HV side ZNzn0 ZN zn Clk Num 0 HV LV side Zzn0 Z zn Clk Num 0 LV side Zz2 Z z Clk Num 2 Not needed ZNz2 ZN z Clk Num 2 Not needed ZNzn2 ZN zn Clk Num ...

Page 703: ...n Clk Num 2 Not needed Yyn2 Y yn Clk Num 2 Not needed Yy4 Y y Clk Num 4 Not needed YNy4 YN y Clk Num 4 Not needed YNyn4 YN yn Clk Num 4 Not needed Yyn4 Y yn Clk Num 4 Not needed Yy6 Y y Clk Num 6 Not needed YNy6 YN y Clk Num 6 HV side YNyn6 YN yn Clk Num 6 HV LV side Yyn6 Y yn Clk Num 6 LV side Yy8 Y y Clk Num 8 Not needed YNy8 YN y Clk Num 8 Not needed YNyn8 YN yn Clk Num 8 Not needed Yyn8 Y yn C...

Page 704: ...Num 7 Not needed Dy11 D y Clk Num 11 Not needed Dyn11 D yn Clk Num 11 Not needed Yz1 Y z Clk Num 1 Not needed YNz1 YN z Clk Num 1 Not needed YNzn1 YN zn Clk Num 1 LV side Yzn1 Y zn Clk Num 1 Not needed Yz5 Y z Clk Num 5 Not needed YNz5 YN z Clk Num 5 Not needed YNzn5 YN zn Clk Num 5 LV side Yzn5 Y zn Clk Num 5 Not needed Yz7 Y z Clk Num 7 Not needed YNz7 YN z Clk Num 7 Not needed YNzn7 YN zn Clk N...

Page 705: ...m the compensated currents See signal description from Monitored data table When a station service transformer is available it can be used to provide current to the high voltage side windings while the low voltage side windings are short circuited This way the current can flow in both the high voltage and low voltage windings The commissioning signals can be provided by other means as well The min...

Page 706: ...e the value for Clock number can be wrong Another reason is that the combination of Winding 1 type and Winding 2 type does not match Clock number This means that the resulting connection group is not supported Example If Winding 1 type is set to Y Winding 2 type is set to y and Clock number is set to Clk num 1 the resulting connection group Yy1 is not a supported combination Similarly if Winding 1...

Page 707: ...Figure 401 Connection example of current transformers of Type 1 1MRS759142 F Protection functions REX640 Technical Manual 707 ...

Page 708: ...Figure 402 Alternative connection example of current transformers of Type 1 Protection functions 1MRS759142 F 708 REX640 Technical Manual ...

Page 709: ...Figure 403 Connection of current transformers of Type 2 and example of the currents during an external fault 1MRS759142 F Protection functions REX640 Technical Manual 709 ...

Page 710: ... can be corrected on both sides of the power transformer with the CT ratio Cor Wnd 1 and CT ratio Cor Wnd 2 settings 4 3 2 8 Signals TR2PTDF Input signals Table 656 TR2PTDF Input signals Name Type Default Description I3P1 SIGNAL Three phase currents 1 I3P2 SIGNAL Three phase currents 2 BLOCK BOOLEAN 0 False Block Table continues on the next page Protection functions 1MRS759142 F 710 REX640 Technic...

Page 711: ... TR2PTDF Settings Table 658 TR2PTDF Group settings Basic Parameter Values Range Unit Step Default Description High operate value 500 3000 Ir 10 1000 Instantaneous stage setting Low operate value 5 50 Ir 1 20 Basic setting for biased operation Slope section 2 10 50 1 30 Slope of the second line of the operat ing characteristics End section 2 100 500 Ir 1 150 Turn point between the second and the th...

Page 712: ...1 2 Type 2 1 Type 1 CT connection type Determined by the directions of the connected cur rent transformers Winding 1 type 1 Y 2 YN 3 D 4 Z 5 ZN 1 Y Connection of the HV side windings Winding 2 type 1 y 2 yn 3 d 4 z 5 zn 1 y Connection of the LV side windings Clock number 0 Clk Num 0 1 Clk Num 1 2 Clk Num 2 4 Clk Num 4 5 Clk Num 5 6 Clk Num 6 7 Clk Num 7 8 Clk Num 8 10 Clk Num 10 11 Clk Num 11 0 Cl...

Page 713: ... where the tap changer is connected to Step of tap 0 60 9 00 0 01 1 50 The percentage change in voltage corresponding one step of the tap changer 4 3 2 10 TR2PTDF Monitored data Table 662 TR2PTDF Monitored data Name Type Values Range Unit Description OPR_A BOOLEAN 0 False 1 True Operate phase A OPR_B BOOLEAN 0 False 1 True Operate phase B OPR_C BOOLEAN 0 False 1 True Operate phase C BLKD2H_A BOOLE...

Page 714: ...monic restraint blocking for PHAR LN phase B BLKD5HPHAR_C BOOLEAN 0 False 1 True 5th harmonic restraint blocking for PHAR LN phase C I_AMPL_A1 FLOAT32 0 00 40 00 xIr Connection group com pensated primary cur rent phase A I_AMPL_B1 FLOAT32 0 00 40 00 xIr Connection group com pensated primary cur rent phase B I_AMPL_C1 FLOAT32 0 00 40 00 xIr Connection group com pensated primary cur rent phase C I_A...

Page 715: ...between winding 1 and 2 phase A I_ANGL_B1_B2 FLOAT32 180 00 180 00 deg Current phase angle diff between winding 1 and 2 phase B I_ANGL_C1_C2 FLOAT32 180 00 180 00 deg Current phase angle diff between winding 1 and 2 phase C I_5H_RAT_A FLOAT32 0 00 1 00 Differential current fifth harmonic ratio phase A I_5H_RAT_B FLOAT32 0 00 1 00 Differential current fifth harmonic ratio phase B I_5H_RAT_C FLOAT32...

Page 716: ...850 identification IEC 60617 identification ANSI IEEE C37 2 device number Stabilized and instantaneous differ ential protection for two or three winding transformers TR3PTDF 3dI 3W 87T3 4 3 3 2 Function block Figure 405 Function block 4 3 3 3 Functionality The stabilized and instantaneous differential protection for two or three winding transformers function TR3PTDF provides up to three three phas...

Page 717: ...o the function through input 4 3 3 4 Analog channel configuration TR3PTDF has three analog group inputs which must be properly configured Table 664 Analog inputs Input Description I3P1 Three phase currents I3P2 Three phase currents I3P3 1 Three phase currents Necessary when Cur rent group 3 type is other than Not in use See the preprocessing function blocks in this document for the possible signal...

Page 718: ...I_C3 TAP_POS Figure 406 Functional module diagram Differential calculation TR3PTDF operates phasewise on the difference of incoming and outgoing currents The positive direction of the currents is towards the protected object Winding 1 usually HV Winding 2 usually LV 1 W I Winding 3 usually tertiary 2 W I 3 W I Figure 407 Single line diagram of the positive direction of the currents in a threewindi...

Page 719: ...below The angle between IX and IY and also between IX and IZ is over 120 degrees while the amplitude of IX is not less than 0 9 MAX IX IY IZ The one with the highest amplitude IX MAX IX IY IZ In case of a two winding transformer having additional restraint additional three phase current set either on the winding 1 or winding 2 side currents are connected to the third winding current inputs This en...

Page 720: ...dified except the removal of the zero sequence current if set active when the currents in other windings are matched with the reference winding if the set phase shift between the windings is not zero The Phase Ref winding setting does not affect settings Phase shift Wnd 1 2 and Phase shift Wnd 1 3 Zero sequence component elimination If a wye connected power transformer neutral is earthed or if the...

Page 721: ...e percentage value is set via the Step of tap setting The operating range of the tap changer is defined by the Min winding tap and Max winding tap settings The Min winding tap setting gives the tap position number resulting from the minimum effective number of winding turns on the side of the transformer where the tap changer is connected Correspondingly the Max winding tap setting gives the tap p...

Page 722: ...hen the delta compensation is done for a Ynd1 connected transformer and the two phases of the inrush currents are otherwise equal but opposite in phase angle their subtraction in a delta compensation results in a very small second harmonic component Because of the small second harmonic component some action must be taken to avoid false tripping of the phase having a too low ratio of the second har...

Page 723: ...the Harmonic deblock 5 setting 5 th harmonic block Start value 5 H Stop value 5 H hysteresis hysteresis t harmonic content of fundamental 1 0 Figure 409 The fifth harmonic blocking limits and the operation when both blocking and deblocking features are enabled through the Harmonic deblock 5 setting Fifth harmonic blocking has a hysteresis to avoid rapid fluctuation between TRUE and FALSE The requi...

Page 724: ...erential current can also be due to something else than an actual fault in the transformer or generator In the case of transformer protection there can be several reasons for the false differential current CT errors Varying tap changer positions if not automatically compensated Transformer no load current Transformer inrush currents Transformer overexcitation during overvoltage situations Transfor...

Page 725: ... of the characteristic are fixed The settings are the same for each phase When the differential current exceeds the operating value determined by the operating characteristic the differential function is activated If the differential current stays above the operating value continuously for a suitable period the OPR_LS output is activated The activation of the OPR_LS output activates the OPERATE ou...

Page 726: ...tion 1 Section 2 Section 3 Id Ir Ib Ir Figure 411 Operation characteristic for biased operation of TR3PTDF The Low operate value setting of the biased stage of the differential function is determined according to the operating characteristics curve Low operatevalue Id 1 Equation 170 The Slope section 2 setting is determined correspondingly Slope section 2 Id Ib 2 2 100 Equation 171 The second turn...

Page 727: ...sformer is rather high at the rated voltage and the rise in voltage by a few percent causes the magnetizing current to increase by tens percent This should be considered in Low operate value Section 2 Section 2 where End section 1 Ib End section 2 is called the influence area of Slope section 2 In this section the variations in the starting ratio affect the slope of the charac teristic that is how...

Page 728: ...eous high stage can be enabled or disabled with the Enable high set setting The corresponding parameter values are True and False The operation of Instantaneous high stage is not biased The instantaneous stage operates and the OPR_HS output is activated when the amplitude of the fundamental frequency component of the differential current exceeds the set operation value High operate value or when t...

Page 729: ...ng signals of the differential function do not prevent the trip signal of the instantaneous differential current stage from being activated When required the operating outputs of Instantaneous high stage can be blocked by the external control signals BLK_OPR_HS or BLOCK OPERATE I_D from Differential calculation High operate value OPR_HS BLOCK BLK_OPR_HS Fault in protected area from Differential ca...

Page 730: ...tion ratio correction The combinations of the connections of the primary current transformers are designated as Type 1 and Type 2 The type needs to be selected separately for the combination of CT connections on the winding 1 and 2 sides as well as for the combination of CT connections on the winding 1 and 3 sides in case of three winding transformer If the positive directions of the winding 1 and...

Page 731: ...N 1 5A N 1 5A N W1 W2 A2 B2 C2 1 5A N 1 5A N 1 5A N A1 B1 C1 W3 W3 Figure 416 Connection of current transformers of Type 2 and example of currents during an external fault Similar connections are done for a three winding transformer If the rated primary current of the current transformers is not equal to the rated current of the power transformer on a side of the transformer setting parameters CT ...

Page 732: ...mall inter turn fault including just a few turns results in an undetectable amount of current until it develops into an earth fault Therefore the differential protection must have a high level of sensitivity and it must be possible to use a sensitive setting without causing unwanted operations for external faults The faulty transformer must be disconnected as fast as possible As the differential p...

Page 733: ...d in three winding transformer applications or two winding transformer applications with two output feeders On the double feeder side of the two winding power transformer the currents from the other feeder are connected to the third three phase current set of the protection relay Current group 3 type to be set as Wnd 2 restraint If the double feeder side is on the input side of the transformer Cur...

Page 734: ...an be corrected on all sides of the power transformer with the CT ratio correction settings I S U nT n n 3 Equation 172 InT Rated load of the power transformer Sn Rated power of the power transformer Un Rated phase to phase voltage Three winding transformer with one set of currents on each side of the transformer 100 MVA YNyn0d1 power transformer 154 kV 14 4 kV 4 37 kV The corresponding rated curr...

Page 735: ...as 185 45 A 400 A 1 07 0 50 xIr 14 4 kV side current 50 MVA 1 732 14 4 kV 2004 7 A TR3PDF seez this as 2004 7 A 4000 A 1 00 0 50 xIr Assume for example a 20 MVA load on the 4 37 kV side and zero on the 14 4 kV side 154kV side current 20 MVA 1 732 154 kV 75 0 A TR3PTDF sees this as 75 A 400 A 1 07 0 20 xIr 4 37kV side current 20 MVA 1 732 4 37 kV 2642 3 A TR3PTDF sees this as 2642 3 A 4000 A 0 30 0...

Page 736: ...ge and low voltage windings and in winding 3 in case of three winding transformer The commissioning signals can also be provided through other means The currents need to be at least 0 015 pu to allow the phase current and angle monitoring A1 B1 C1 3 phase low voltage source YNyn0 A2 B2 C2 Figure 420 Low voltage test arrangement The three phase low voltage source can be the station service transfor...

Page 737: ...NGL_C1_C3 should show 180 There can be several reasons if this is not the case If the angle values are 0 most probably the value given for CT connection 1 2 or CT connection 1 3 is wrong If the angle values are something else the value for Phase shift Wnd 1 2 or Phase shift Wnd 1 3 may be wrong Table 667 Angle outputs when settings CT connection 1 2 and CT connection 1 3 match the actual CT connec...

Page 738: ..._ANGL_A1_A3 60 Winding 1 phase B connected as phase A I_ANGL_B1_B3 60 Winding 1 phase A connected as phase B I_ANGL_C1_C3 180 OK Table 669 Angle outputs when settings CT connection 1 2 and CT connection 1 3 match the actual CT connections on windings 1 2 and 3 but the phase order is wrong on winding 2 Angle output name Angle value Possible reason if not OK I_ANGL_A1_B1 120 OK I_ANGL_B1_C1 120 OK I...

Page 739: ...e attention should be paid to the CTs Normally it is not possible to dimension the CTs so that they repeat currents with high DC components without saturating when the residual flux of the current transformer is high TR3PTDF operates reliably even though the CTs are partially saturated The purpose of the following current transformer recommendations is to secure the stability of the relay at high ...

Page 740: ...at the current required for instantaneous tripping The CTs should be able to reproduce the asymmetric fault current without saturating within the next 10 ms after the occurrence of the fault to secure that the operating times of the protection relay comply with the times stated in Chapter 4 3 3 12 Technical data The accuracy limit factors corresponding to the actual burden of the phase current tra...

Page 741: ...c of the fault current is almost the same as that of the transformer the typical value being 100 ms F K I T 1 e 1 40 a r kmax dc Tm ω Tdc Equation 175 Ikmax 10 pu Tdc 100 ms ω 100π Hz Tm 10 ms Kr 1 Re energizing against a fault occurring further down in the network The protection must be stable during the re energization against a fault on the line In this case the existence of remanence is very p...

Page 742: ...ctual accuracy limit factor due to oversizing the CT Fa 1500 1000 30 45 In differential protection it is important that the accuracy limit factors Fa at both sides of the phase CTs correspond with each other that is the burdens of the CTs on both sides should be as equal as possible If high inrush or start currents with high DC components flow through the protected object when it is connected to t...

Page 743: ...Slope of the second line of the operat ing characteristics End section 2 100 500 Ir 1 150 Turn point between the second and the third line of the op erating characteris tics Restraint mode 5 Waveform 6 2 h waveform 8 5 h waveform 9 2 h 5 h wav 9 2 h 5 h wav Restraint mode Start value 2 H 7 20 1 15 2 harmonic block ing ratio Start value 5 H 10 50 1 35 5 harmonic block ing ratio Stop value 5 H 10 50...

Page 744: ...2 3 1 Not eliminated Elimination of the zero sequence cur rent Phase shift Wnd 1 2 0 0 359 9 deg 0 1 0 0 Setting the phase shift between winding 1 and 2 in degrees Phase shift Wnd 1 3 0 0 359 9 deg 0 1 0 0 Setting the phase shift between winding 1 and 3 in degrees Min winding tap 36 36 1 17 The tap position number resulting the minimum num ber of effective winding turns on the side of the transfor...

Page 745: ...BLKD2H_A BOOLEAN 0 False 1 True 2nd harmonic restraint block phase A status BLKD2H_B BOOLEAN 0 False 1 True 2nd harmonic restraint block phase B status BLKD2H_C BOOLEAN 0 False 1 True 2nd harmonic restraint block phase C status BLKD5H_A BOOLEAN 0 False 1 True 5th harmonic restraint block phase A status BLKD5H_B BOOLEAN 0 False 1 True 5th harmonic restraint block phase B status BLKD5H_C BOOLEAN 0 F...

Page 746: ... com pensated primary cur rent phase C I_AMPL_A2 FLOAT32 0 00 40 00 xIr Connection group com pensated secondary current phase A I_AMPL_B2 FLOAT32 0 00 40 00 xIr Connection group com pensated secondary current phase B I_AMPL_C2 FLOAT32 0 00 40 00 xIr Connection group com pensated secondary current phase C I_AMPL_A3 FLOAT32 0 00 40 00 xIr Connection group com pensated tertiary cur rent phase A I_AMP...

Page 747: ...ent phase angle phase A to B winding 3 I_ANGL_B3_C3 FLOAT32 180 00 180 00 deg Current phase angle phase B to C winding 3 I_ANGL_C3_A3 FLOAT32 180 00 180 00 deg Current phase angle phase C to A winding 3 I_ANGL_A1_A2 FLOAT32 180 00 180 00 deg Current phase angle diff between winding 1 and 2 phase A I_ANGL_B1_B2 FLOAT32 180 00 180 00 deg Current phase angle diff between winding 1 and 2 phase B I_ANG...

Page 748: ...0 ms 17 ms 35 ms 18 ms 40 ms 20 ms Reset time Typically 40 ms Reset ratio Typically 0 96 Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 4 3 4 Numerically stabilized low impedance restricted earth fault protection LREFPNDF ANSI 87NLI 4 3 4 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Numerically stabilized low im...

Page 749: ...ut Description I3P Three phase currents IRES Residual current measured See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 679 Special conditions Condition Description IRES measured The function requires that the current meas ured from the neutral side is connected Improper analog...

Page 750: ...ent An earth fault occurring in the protected area that is between the phase CTs and the neutral connection CT causes a differential current The directions that is the phase difference of the residual current and the neutral current are considered in the operation criteria to maintain selectivity A correct value for CT connection type is determined by the connection polarities of the current trans...

Page 751: ...23 Operating characteristics of the stabilized earth fault protection function Figure 424 Setting range of the operating characteristics for the stabilized differential current principle of the earth fault protection function The Operate value setting is used for defining the characteristics of the function The differential current value required for tripping is constant at the stabilizing current...

Page 752: ...king is disabled when Restraint mode is set to None and enabled when set to Harmonic2 Timer Once activated the Timer activates the START output The time characteristic is according to DT When the operation timer has reached the value set by Minimum operate time the OPERATE output is activated If the fault disappears before the module operates the reset timer is activated If the reset timer reaches...

Page 753: ...f the transformer if an earthing transformer zig zag transformer is used there In LREFPNDF the difference of the fundamental component of all three phase currents and the neutral current is provided to the differential element to detect the earth fault in the transformer winding based on the numerical stabilized differential current principle Connection of current transformers The connections of t...

Page 754: ...current have opposite directions at an external earth fault situation Figure 426 Connection of the current transformers of Type 1 The connected phase currents and the neutral current have opposite directions at an external earth fault situation Protection functions 1MRS759142 F 754 REX640 Technical Manual ...

Page 755: ...ual directions at an external earth fault situation Internal and external faults LREFPNDF does not respond to any faults outside the protected zone An external fault is detected by checking the phase angle difference of the neutral current and the sum of the phase currents When the difference is less than 90 degrees the operation is internally restrained or blocked Hence the protection is not sens...

Page 756: ...ult Uzs Figure 429 Current flow in all the CTs for an external fault A B C a b c Ia 0 I Ib 0 I c 0 I Uzs Io zone of protection Ifault IN Io IN Reference is Neutral Current Restrain for external fault Operate for internal fault For internal fault s o u r c e Figure 430 Current flow in all the CTs for an internal fault Protection functions 1MRS759142 F 756 REX640 Technical Manual ...

Page 757: ...f the transformer to be protected increases momentarily when the voltage returns to normal after the clearance of a fault outside the protected area The sympathetic inrush is caused by the energization of a transformer running in parallel with the protected transformer already connected to the network Blocking the starting of the restricted earth fault protection at the magnetizing inrush is based...

Page 758: ... Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On CT connection type 1 Type 1 2 Type 2 2 Type 2 CT connection type Table 685 LREFPNDF Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time 4 3 4 9 LREFPNDF Monitored data Table 686 LREFPNDF Monitored data Name Type Values Range Unit Description START...

Page 759: ... 4 3 5 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number High impedance based restricted earth fault protection HREFPDIF dIoHi 87NHI 4 3 5 2 Function block Figure 431 Function block 4 3 5 3 Functionality The high impedance based restricted earth fault protection function HREFPDIF is used for the restricted earth fault protection o...

Page 760: ... in this document The configuration can be written to the protection relay once the mismatch is corrected 4 3 5 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The operation of HREFPDIF can be described using a module diagram All the modules in the diagram are explained in the next sections Level detector B...

Page 761: ...he operation timer is frozen to the prevailing value In the Block all mode the whole function is blocked and the timers are reset In the Block OPERATE output mode the function operates normally but the OPERATE output is not activated 4 3 5 6 Application In solidly earthed systems the restricted earth fault protection is always deployed as a complement to the normal transformer differential protect...

Page 762: ... of protection The stabilization is obtained by a stabilizing resistor in the differential circuit This method requires that all the CTs used have a similar magnetizing characteristic same ratio and relatively high knee point voltage CTs on each sides are connected in parallel along with a relay measuring branch as shown in Figure 434 The measuring branch is a series connection of stabilizing resi...

Page 763: ...ng branch is below the relay operating current during out of zone faults As a result the operation is stable during the saturation and can still be sensitive at the non saturated parts of the current waveform as shown in Figure 435 In case of an internal fault the fault current cannot circulate through the CTs but it flows through the measuring branch and the protection operates Partial CT saturat...

Page 764: ...uation 180 I kmax the highest through fault current n the turns ratio of the CT R in the secondary internal resistance of the CT R m the resistance of the longest loop of secondary circuit Additionally it is required that the current transformers knee point voltages U k are at least twice the stabilizing voltage value U s 4 3 5 8 Recommendations for current transformers The sensitivity and reliabi...

Page 765: ...om growing too high it is advisable to use current transformers the secondary winding resistance of which is of the same size as the resistance of the measuring loop As the impedance of the protection relay alone is low a stabilizing resistor is needed The value of the stabilizing resistor is calculated with the formula R U I s s rs Equation 183 R s the resistance of the stabilizing resistor U s t...

Page 766: ...principle the highest through fault should be known However when the necessary data are not available approximates can be used Small power transformers I kmax 16 x I n corresponds to z k 6 and infinite grid Large power transformers I kmax 12 x I n corresponds to z k 8 and infinite grid Generators and motors I kmax 6 x I n Where I n rated current and z k short circuit impedance of the protected obj...

Page 767: ...ltage U max ignoring the CT saturation during the fault is calculated with the equation U I n R R R I n R k in in m s k in s max max max Equation 187 I kmaxin the maximum fault current inside the zone in primary amps n the turns ration of the CT R in the internal resistance of the CT in ohms R m the resistance of the longest loop of the CT secondary circuit in ohms R s the resistance of the stabil...

Page 768: ...ary current is 1200 A and the secondary current is 5 A R in 0 26 Ω value given by the manufacturer U k 40 V value given by the manufacturer I e 0 055 A value given by the manufacturer R m 1 81 Ω km 2 0 05 km 0 181 Ω 0 18 Ω U V V s 12600 0 26 0 18 240 23 According to the criterion the value of U k should be 2 U s 2 23 V 46 V It depends on if the stability of the scheme is achieved with U k 40 V Oth...

Page 769: ...n _ 2 0 11 5 2 2 The resistance of the stabilizing resistor can be calculated R s U s I rs 34 V 0 11 A 309 Ω However the sensitivity can be calculated more accurately when the actual values of I u and I rs are known The stabilizing resistor of the relay is chosen freely in the above example and it is assumed that the resistor value is not fixed Example 2a n n m u s Figure 437 Restricted earth faul...

Page 770: ... earlier I m 0 5 I e gives a realistic value for I prim in Equation 185 If I u 0 and I rs m 0 5 I e the value for the sensitivity is I prim n m I e 1000 4 0 012 A 48 A 6 x I n I rs 4 0 5 0 012 A 0 024 A The setting value can be calculated with Operatevalue I I A A rs CT n _ 2 0 024 1 2 4 The resistance of the stabilizing resistor can now be calculated R s U s I rs 78 V 2 I e 78 V 2 0 012 A 3250 Ω ...

Page 771: ...ettings Basic Parameter Values Range Unit Step Default Description Operate value 1 0 50 0 In 0 1 5 0 Low operate value percentage of the nominal current Minimum operate time 20 300000 ms 1 20 Minimum operate time Table 692 HREFPDIF Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 693 HREFPDIF Non group settings Advanced ...

Page 772: ... set value or 0 002 In Start time 1 2 Minimum Typical Maximum IFault 2 0 set Oper ate value IFault 10 0 set Op erate value 16 ms 11 ms 21 ms 13 ms 23 ms 14 ms Reset time Typically 40 ms Reset ratio Typically 0 96 Retardation time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20 ms 4 3 6 High impedance differential protection HIxPDIF ANSI 87_A 87_B 87_C 1 Current before ...

Page 773: ...when the differential current exceeds the set limit The operate time characteristics are according to definite time DT The function contains a blocking functionality It is possible to block the function outputs timer or the whole function 4 3 6 4 Analog channel configuration HIxPDIF has one analog group input which must be properly configured Table 696 Analog inputs Input Description I3P Three pha...

Page 774: ...s START BLOCK Level detector Blocking logic OPERATE t Timer t Timer I3P I_A START BLOCK Level detector Blocking logic OPERATE t Timer t Timer I3P I_B START BLOCK Level detector Blocking logic OPERATE t Timer t Timer I3P I_C Figure 439 Functional module diagram The module diagram illustrates all the phases of the function Functionality for phases A B and C is identical All three phases have indepen...

Page 775: ...rizontal communication input or an internal signal of the protection relay s program The influence of the BLOCK signal activation is preselected with the global setting Blocking mode The Blocking mode setting has three blocking methods In the Freeze timers mode the operation timer is frozen to the prevailing value In the Block all mode the whole function is blocked and the timers are reset In the ...

Page 776: ...ndary winding resistances R in and connection wire resistances R m 2 are also shown in Figure 441 Figure 441 demonstrates a simplified circuit consisting only of one incoming and outgoing feeder To keep it simple the voltage dependent resistor R u is not included The wiring resistances are presented as total wiring resistances R m1 and R m2 R m1 is the maximum wiring resistance concerning all inco...

Page 777: ...through only one CT its secondary emf magnetizes the opposite CT that is E 1 E 2 Id Rs Rm1 Rin1 Rin2 Rm2 E1 U E2 U E1 E2 Figure 442 Equivalent circuit in case of in zone fault Figure 443 shows CT saturation at a through fault that is out of zone situation The magnetization impedance of a saturated CT is almost zero The saturated CT winding can be presented as a short circuit When one CT is saturat...

Page 778: ...remains stable non operative during the saturated parts of the CT secondary current waveform the non saturated part of the current waveform causes the protection to operate Figure 444 Secondary waveform of a saturated CT The secondary circuit voltage can easily exceed the isolation voltage of the CTs connection wires and the protection relay because of the stabilizing resistance and CT saturation ...

Page 779: ...the total instantaneous incoming current is equal to the total instantaneous outgoing current and the difference current is negligible A fault in the busbar results in an imbalance between the incoming and the outgoing current The difference current flows through the protection relay which generates a trip signal Figure 445 Phase segregated single busbar protection employing high impedance differe...

Page 780: ... Thus the current flowing through the bus coupler needs to be considered in calculating differential current During normal condition the summation of the current on each bus section is zero However if there is a fault in any busbar section the difference current is no longer zero and the protection operates Figure 446 Differential protection on busbar with bus coupler Single phase representation 4...

Page 781: ... A I kmax 25 kA 10 feeders per protected zone including bus coupler and incomer CT data is assumed to be CT 2000 1 A R in 15 75 Ω U kn 436 V I e 7 mA at U kn R m 1Ω The stabilizing voltage is calculated using the formula 1MRS759142 F Protection functions REX640 Technical Manual 781 ...

Page 782: ...34 Equation 192 The resistance of the stabilizing resistor is calculated based on Equation 193 R V A S 209 37 0 034 6160 Ω Equation 193 The calculated value is the maximum value for the stabilizing resistor If the value is not available the next available value below should be selected and the protection relay setting current is tuned according to the selected resistor For example in this case the...

Page 783: ... the stabilizing voltage can be available from the VDR manual assuming that to be approximately 2 mA at stabilizing voltage Iu A 0 002 Equation 199 The sensitivity of the protection can be recalculated taking into account the leakage current through the VDR as per Equation 200 I A A A A prim 2000 0 035 10 0 0034 0 002 142 Equation 200 4 3 6 8 Signals HIAPDIF Input signals Table 697 HIAPDIF Input s...

Page 784: ... BOOLEAN 0 False Block signal for acti vating the blocking mode HIAPDIF Output signals Table 700 HIAPDIF Output signals Name Type Description START BOOLEAN Start OPERATE BOOLEAN Operate HIBPDIF Output signals Table 701 HIBPDIF Output signals Name Type Description START BOOLEAN Start OPERATE BOOLEAN Operate HICPDIF Output signals Table 702 HICPDIF Output signals Name Type Description START BOOLEAN ...

Page 785: ...1 0 200 0 In 1 0 5 0 Operate value per centage of the nominal current Minimum operate time 20 300000 ms 10 20 Minimum operate time Table 707 HIBPDIF Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 708 HIBPDIF Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 10 ...

Page 786: ... erate time HIAPDIF Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status HIBPDIF Monitored data Table 713 HIBPDIF Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time HIBPDIF Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status HICPDIF Monitored data Table 714 HICPDIF Monitored data Name Type Values Range Unit Description START_...

Page 787: ...t value 7 ms 9 ms 11 ms Reset time Typically 40 ms Reset ratio Typically 0 96 Retardation time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20 ms 1 Measurement mode default depends on stage current before fault 0 0 In fn 50 Hz fault current with nominal frequency injected from random phase angle results based on statistical distribution of 1000 measurements 2 Measured ...

Page 788: ... function The stability of the differential protection is enhanced by a DC restraint feature This feature decreases the sensitivity of the differential protection optionally for a temporary time period to avoid an unnecessary disconnection of the machine during the external faults that have a fault current with high DC currents MPDIF also includes a CT saturation based blocking which prevents unne...

Page 789: ...tions OPR_LS Through fault detection BLK_OPR_LS BLOCK BLK_OPR_HS I3P1 I3P2 OPERATE INT_BLKD DC restraint Differential and bias calculation OPR_HS Biased low stage CT saturation based blocking Instan taneous high stage I_A1 I_B1 I_C1 I_A2 I_B2 I_C2 Figure 449 Functional module diagram Differential and bias calculation Differential calculation module calculates the differential current The different...

Page 790: ... essential for ensuring the correct operation of the protection in case of the CT saturation In a through fault situation CTs can saturate because of a high fault current magnitude Such AC saturation does not happen immediately when the fault begins Thus the TF module sees the fault as external because the bias current is high but the differential current remains low If the AC saturation then occu...

Page 791: ... faults with lower currents Biased low stage The current differential protection needs to be biased because of the possible appearance of a differential current which can be due to something else than an actual fault in the machine In case of differential protection a false differential current can be caused by CT errors CT saturation at high currents passing through the machine The differential c...

Page 792: ...comparison to the change in the load current The End section 2 setting allows for CT errors In section 3 where I b I n End section 2 the slope of the characteristic can be set by Slope section 3 that defines the increase in the differential current to the corresponding increase in the biasing current The required differential current for tripping at a certain stabilizing current level can be calcu...

Page 793: ...ion of current Instantaneous high stage The differential protection includes an unbiased instantaneous high stage The instantaneous stage operates and the OPR_HS output is activated when the amplitude of the fundamental frequency component of the differential current exceeds the set High operate value or when the instantaneous peak values of the differential current exceed 2 5 High operate value T...

Page 794: ...ses of the stator windings normally causes high fault currents The short circuit creates a risk of damages to the insulation windings and stator core The high short circuit currents cause strong current forces which can damage other components in the machine The short circuit can also initiate explosion and fire When a short circuit occurs in a machine there is a damage that has to be repaired The...

Page 795: ...short circuit it gives an increased risk of a power system collapse Besides there is a production loss for every unwanted trip of the machine Therefore preventing the unwanted disconnection of machines has a great economical value Recommendations for current transformers The more important the object to be protected is the more attention is paid to the current transformers It is not normally possi...

Page 796: ...ransformer to be used in differential protection must fulfill the requirement F K Ik T e a r dc T m Tdc max ω 1 1 Equation 210 Ik max The maximum through going fault current in I R at which the protection is not allowed to operate T dc The primary DC time constant related to Ik max ω The angular frequency that is 2 x π x f n T m The time to saturate that is the duration of the saturation free tran...

Page 797: ...ence is very probable It is assumed to be 40 percent here On the other hand the fault current is now smaller and since the ratio of the resistance and reactance is greater in this location having a full DC offset is not possible Furthermore the DC time constant T dc of the fault current is now smaller assumed to be 50 ms here Assuming the maximum fault current is 30 percent lower than in the bus f...

Page 798: ... as close to each other as possible If high inrush or start currents with high DC components pass through the protected object when it is connected to the network special attention is required for the performance and the burdens of the current transformers and the settings of the function block Connection of current transformers The connections of the primary current transformers are designated as...

Page 799: ...Figure 452 Connection of current transformer of Type 1 example 1 Figure 453 Connection of current transformer of Type 1 example 2 1MRS759142 F Protection functions REX640 Technical Manual 799 ...

Page 800: ...Figure 454 Connection of current transformer of Type 2 example 1 Figure 455 Connection of current transformer of Type 2 example 2 Protection functions 1MRS759142 F 800 REX640 Technical Manual ...

Page 801: ...e CT saturates This is known as DC saturation Figure 456 AC saturation When having a short circuit in a power line the short circuit current contains a DC component The magnitude of the DC component depends on the phase angle when the short circuit occurs Figure 457 shows the secondary current of the CT in the fault situation Because of the DC component the flux reaches its maximum value at 0 07 s...

Page 802: ...HS BOOLEAN Operate from high set INT_BLKD BOOLEAN Internal block status 4 3 7 8 MPDIF Settings Table 719 MPDIF Group settings Basic Parameter Values Range Unit Step Default Description Low operate value 5 30 Ir 1 5 Basic setting for the stabilized stage start High operate value 100 1000 Ir 10 500 Instantaneous stage operate value Slope section 2 10 50 1 30 Slope of the second line of the operat in...

Page 803: ... Values Range Unit Description OPR_A BOOLEAN 0 False 1 True Operate phase A OPR_B BOOLEAN 0 False 1 True Operate phase B OPR_C BOOLEAN 0 False 1 True Operate phase C INT_BLKD_A BOOLEAN 0 False 1 True Internal block status phase A INT_BLKD_B BOOLEAN 0 False 1 True Internal block status phase B INT_BLKD_C BOOLEAN 0 False 1 True Internal block status phase C ID_A FLOAT32 0 00 80 00 xIr Differential c...

Page 804: ... off Status IL1 diff 1 FLOAT32 0 00 80 00 Measured differential current amplitude phase IL1 IL2 diff 1 FLOAT32 0 00 80 00 Measured differential current amplitude phase IL2 IL3 diff 1 FLOAT32 0 00 80 00 Measured differential current amplitude phase IL3 IL1 bias 1 FLOAT32 0 00 80 00 Measured bias current amplitude phase IL1 IL2 bias 1 FLOAT32 0 00 80 00 Measured bias current amplitude phase IL2 IL3 ...

Page 805: ...gh stage 9 ms 13 ms 19 ms Reset time Typically 40 ms Reset ratio Typically 0 95 Retardation time 20 ms Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 1MRS759142 F Protection functions REX640 Technical Manual 805 ...

Page 806: ...aracteristic is according to the definite time DT This function contains a blocking functionality It is possible to block the function outputs timers or the function itself 4 3 8 4 Analog channel configuration MHZPDIF has one analog group input which must be properly configured Table 724 Analog inputs Input Description I3P Three phase currents See the preprocessing function blocks in this document...

Page 807: ...start duration value START_DUR which indicates the percentage ratio of the start situation and the set operation time The value is available in the Monitored data view The activation of the BLOCK signal resets the Timer and deactivates the START and OPERATE outputs 4 3 8 6 Application MHZPDIF provides the winding short circuit and earth fault protection for motors The high impedance or flux balanc...

Page 808: ... current during out of zone faults As a result the operation is stable during the saturation and can still be sensitive at the undistorted parts of the current waveform Figure 460 Three phase differential protection for motors based on highimpedance principle In case of an internal fault the fault current cannot circulate through the CTs It flows through the measuring branch and the protection ope...

Page 809: ...ng principle no stabilizing resistors are needed The configuration however requires the use of core balance current transformers The compared currents the one at the line end and the other at the neutral end are both measured by the same core balance current transformer In this scheme the currents flowing through one core balance transformer cancel each other out when there is no fault within the ...

Page 810: ...impedance principle or stabilized three phase differential protection must be used Protection functions 1MRS759142 F 810 REX640 Technical Manual ...

Page 811: ...and the burden of the branches are not equal the maximum burden equal to 3 2 Ω should be used for calculating the stabilized voltage Figure 463 High impedance differential protection with different CT burden value on each branch The stabilizing voltage that is the voltage appearing across the measuring branch during an out of zone fault is calculated assuming that one of the CTs connected in paral...

Page 812: ... of the stabilizing resistor U s The stabilizing voltage of the protection relay I rs The value of the Operate value setting in secondary amps The stabilizing resistor should be capable to dissipate high energy within a very short time therefore the wire wound type resistor should be used Because of the possible CT inaccuracy which might cause some current through the stabilizing resistor in a nor...

Page 813: ...lass X current transformers or it can be estimated with Equation 217 4 The sensitivity I prim is calculated with Equation 216 If the achieved sensitivity is sufficient the present CT is chosen A CT with a bigger core is chosen if a better sensitivity is needed If a Class X CT is not used an estimate for Ukn is calculated using Equation 216 U F I R S I kn n n in n n 0 8 2 2 2 Equation 217 F n The r...

Page 814: ...which is the insulation level for which the IED is tested For example the maximum fault current in case of a fault inside the zone is 12 6 kA in primary CT is of 1250 5 A that is ratio n 240 and knee point voltage is 81 V The stabilizing resistor is 330 Ohms U A V max Ω 12600 240 330 17325 Equation 220 u kV 2 2 81 17325 81 3 34 Equation 221 As the peak voltage ȗ 3 2 kV VDR must be used In some cas...

Page 815: ... 6 kV In 770 A Ikmax 4620 A 6 In out of zone fault Ikmaxin 9 24 kA 12 In in zone fault Table 726 Assumed CT data Quantity Value CT 1000 1 A Rin 15 3 Ω Ukn 323 V Ie 35 mA at Ukn Figure 464 Example calculation for high impedance differential protection only one phase is presented in detail The length of the secondary circuit loop is 200 m and the area of the cross section is 2 5 mm2 Resistance at 75...

Page 816: ...magnetizing currents of all connected CTs to obtain adequate protection stability I mA mA rs 2 8 5 17 Equation 226 The resistance of the stabilizing resistor is calculated based on equation R V A s 78 7 0 017 4629 Ω Equation 227 The calculated value 4629 Ω is the maximum value for the stabilizing resistor If this value is not available the next available value downwards should be chosen and the pr...

Page 817: ... than 2 kV The leakage current through the varistor at the stabilizing voltage can be available from the varistor manual assuming that to be approximately 2 mA at stabilizing voltage Iu A 0 002 Equation 233 The sensitivity of the protection can be re calculated taking into account the leakage current through the varistor as per equation I A A A A prim 1000 0 020 2 0 0085 0 002 39 Equation 234 4 3 ...

Page 818: ... Description Operation 1 on 5 off 1 on Operation Off On Table 731 MHZPDIF Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 0 Reset delay time 4 3 8 11 MHZPDIF Monitored data Table 732 MHZPDIF Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time ID_A FLOAT32 0 00 80 00 xIn...

Page 819: ...acy in definite time mode 1 0 of the set value of 20 ms 4 4 Unbalance protection 4 4 1 Negative sequence overcurrent protection NSPTOC ANSI 46M 4 4 1 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Negative sequence overcurrent pro tection NSPTOC I2 M 46M 1 Measurement mode Peak to Peak current before fault 0 0 In fn 50 Hz fault...

Page 820: ...ides current dependent timer characteristics The function contains a blocking functionality It is possible to block function outputs timers or the function itself 4 4 1 4 Analog channel configuration NSPTOC has one analog group input which must be properly configured Table 734 Analog signals Input Description I3P Three phase currents See the preprocessing function blocks in this document for the p...

Page 821: ...e parameter A Curve parameter B Curve parameter C Curve parameter D and Curve parameter E If a drop off situation happens that is a fault suddenly disappears before the operate delay is exceeded the timer reset state is activated The functionality of the timer in the reset state depends on the combination of the Operating curve type Type of reset curve and Reset delay time settings When the DT cha...

Page 822: ...nitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting in Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the protection relay s program The influence of the B...

Page 823: ...pe Default Description I3P SIGNAL Three phase currents BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode ENA_MULT BOOLEAN 0 False Enable signal for cur rent multiplier NSPTOC Output signals Table 736 NSPTOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start 4 4 1 8 NSPTOC Settings Table 737 NSPTOC Group settings Basic Parameter Values Range Unit Ste...

Page 824: ...on Operation Off On Curve parameter A 0 0086 120 0000 0 0001 28 2000 Parameter A for customer program mable curve Curve parameter B 0 0000 0 7120 0 0001 0 1217 Parameter B for customer program mable curve Curve parameter C 0 02 2 00 0 01 2 00 Parameter C for customer program mable curve Curve parameter D 0 46 30 00 0 01 29 10 Parameter D for customer program mable curve Curve parameter E 0 0 1 0 0...

Page 825: ...ion time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20 ms Operate time accuracy in inverse time mode 5 0 of the theoretical value or 20 ms 3 Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 4 4 2 Directional negative sequence overcurrent protection DNSPDOC ANSI 67Q 4 4 2 1 Identification Function description IEC 61850 identification IEC 60617 identificati...

Page 826: ...hree phase currents IRES 3 Residual current measured or calculated Necessary when Operating quantity is Re sidual or Residual calc U3P Three phase voltages See the preprocessing function blocks in this document for the possible signal sources The GRPOFF signal is available in the function block called Protection There are a few special conditions which must be noted with the configuration Table 74...

Page 827: ...ve seq or Residual The value of operating quantity I_OPER is also available in the Monitored data view Irrespective of the operating quantity selected directional calculation is always determined using the negative sequence current Directional calculation Directional calculation compares the negative sequence current phasor with the negative sequence voltage phasor that is the polarizing quantity ...

Page 828: ...operation time The value is available in the Monitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting in Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the pr...

Page 829: ...is calculated as shown below and is available in the Monitored data view ANGLE U I RCA φ φ φ 2 2 Equation 235 Based on the ANGLE value the direction information DIRECTION is evaluated and is made available in the Monitored data view Table 745 Momentary direction value for monitored data view Criterion for direction information Value for DIRECTION ANGLE_X is not in any of the defined sectors or the...

Page 830: ...quence elements is that the negative sequence component is insensitive to zero sequence mutual coupling The negative sequence is also used where the source is not strong enough because with such a source the value of the negative sequence near the protection relay has higher magnitude 4 4 2 8 Signals DNSPDOC Input signals Table 746 DNSPDOC Input signals Name Type Default Description I3P SIGNAL Thr...

Page 831: ...ttings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 751 DNSPDOC Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time Allow Non Dir 0 False 1 True 0 False Allows prot activa tion as non dir when dir info is in valid Min operate current 0 01 1 00 xIn 0 01 0 01 ...

Page 832: ...ms Reset time Typically 40 ms Reset ratio Typically 0 96 Retardation time 35 ms Operate time accuracy 1 0 of the set value of 20 ms Suppression of harmonics RMS No suppression DFT 50 dB at f n fn where n 2 3 4 5 Peak to Peak No suppression 4 4 3 Phase discontinuity protection PDNSPTOC ANSI 46PD 4 4 3 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE ...

Page 833: ...le 754 Analog signals Input Description I3P Three phase currents See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks...

Page 834: ...y Operate delay time the OPERATE output is activated If the fault disappears before the module operates the reset timer is activated If the reset timer reaches the value set by Reset delay time the operate timer resets and the START output is deactivated The timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operation time Th...

Page 835: ...PDNSPTOC is based on the ratio of the positive sequence and negative sequence currents This gives a better sensitivity and stability compared to plain negative sequence current protection since the calculated ratio of positive sequence and negative sequence currents is relatively constant during load variations The unbalance of the network is detected by monitoring the negative sequence and positi...

Page 836: ...se currents BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode PDNSPTOC Output signals Table 756 PDNSPTOC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start 4 4 3 8 PDNSPTOC Settings Table 757 PDNSPTOC Group settings Basic Parameter Values Range Unit Step Default Description Start value 10 100 1 10 Start value Operate delay time 100 30000 ms 1 100 Op...

Page 837: ... 100 00 Ratio of start time op erate time RATIO_I2_I1 FLOAT32 0 00 999 99 Measured current ratio I2 I1 PDNSPTOC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 4 3 10 Technical data Table 761 PDNSPTOC Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured current fn 2 Hz 2 of the set value Start time 70 ms Reset time Typically 40 ms Reset ratio T...

Page 838: ...in the opposite direction The function contains a blocking functionality It is possible to block function outputs timer or the function itself 4 4 4 4 Analog input configuration PREVPTOC has one analog group input which must be properly configured Table 762 Analog inputs Input Description I3P Three phase currents See the preprocessing function blocks in this document for the possible signal source...

Page 839: ...alue is available in the monitored data view 4 4 4 6 Application The rotation of a motor in the reverse direction is not a desirable operating condition When the motor drives fans and pumps for example and the rotation direction is reversed due to a wrong phase sequence the driven process can be disturbed and the flow of the cooling air of the motor can become reversed too With a motor designed on...

Page 840: ...r Values Range Unit Step Default Description Start value 0 05 1 00 xIn 0 01 0 75 Start value Operate delay time 100 60000 ms 10 100 Operate delay time Table 766 PREVPTOC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On 4 4 4 9 PREVPTOC Monitored data Table 767 PREVPTOC Monitored data Name Type Values Range Unit Description STA...

Page 841: ...urrent pro tection for machines MNSPTOC I2 M 46M 4 4 5 2 Function block Figure 476 Function block 4 4 5 3 Functionality The negative sequence overcurrent protection for machines function MNSPTOC protects electric motors from phase unbalance A small voltage unbalance can produce a large negative sequence current flow in the motor For example a 5 percent voltage unbalance produces a stator negative ...

Page 842: ...on setting The corresponding parameter values are On and Off The operation of MNSPTOC can be described by using a module diagram All the modules in the diagram are explained in the next sections OPERATE BLK_RESTART START BLOCK I3P I2 Level detector t Timer t ST_EMERG_ENA Figure 477 Functional module diagram Level detector The calculated negative sequence current is compared to the Start value sett...

Page 843: ...of the T_ENARESTART is immediately set to False This disables BLK_RESTART and in turn makes the restart of the motor possible The timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operation time The value is available in the monitored data view The T_ENARESTART output indicates the duration for which the BLK_RESTART output r...

Page 844: ...selected curve type and the setting values used The Minimum operate time and Maximum operate time settings define the minimum operate time and maximum operate time possible for the IDMT mode For setting these parameters a careful study of the particular IDMT curves is recommended Inv curve A The inverse time equation for curve type A is t s k I Ir 2 2 Equation 237 t s Operate time in seconds k Set...

Page 845: ... s a b 100 Equation 238 t s Reset time in seconds a set Cooling time b percentage of start time elapse START_DUR When the reset period is initiated the time for which START has been active is saved If the fault reoccurs that is the negative sequence current rises above the 1MRS759142 F Protection functions REX640 Technical Manual 845 ...

Page 846: ...erate timer is reset and the saved values of start time and integration are cleared Inv curve B The inverse time equation for curve type B is t s k I I I I r S r 2 2 2 Equation 239 t s Operate time in seconds k Machine time Mult I 2 Negative sequence current I S Set Start value I r Set Rated current Protection functions 1MRS759142 F 846 REX640 Technical Manual ...

Page 847: ...ue the subtraction in the denominator becomes negative and the cumulative sum starts to decrease The decrease in the sum indicates the cooling of the machine and the cooling speed depends on the value of the negative sequence current If the sum reaches zero without a fault being detected the accumulation stops and the timer is reset If the reset time set through the Cooling time setting elapses wi...

Page 848: ...indings inducing negative sequence voltage in the rotor windings This can result in a high rotor current that damages the rotor winding The frequency of the induced current is approximately twice the supply frequency Due to skin effect the induced current with a frequency double the supply frequency encounters high rotor resistance which leads to excessive heating even with phase currents with val...

Page 849: ...erate delay time 100 120000 ms 10 1000 Operate delay time Table 773 MNSPTOC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Maximum operate time 500000 7200000 ms 1000 1000000 Max operate time regardless of the inverse characteris tic Minimum operate time 100 120000 ms 1 100 Minimum operate time for IDMT curves Cooling time 5...

Page 850: ...40 ms Reset ratio Typically 0 96 Retardation time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20 ms Operate time accuracy in inverse time mode 5 0 of the theoretical value or 20 ms 3 Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 4 4 5 12 Technical revision history Table 777 MNSPTOC Technical revision history Product connectivity level Technical revision...

Page 851: ... two phases or three phases PHPTOV includes both definite time DT and inverse definite minimum time IDMT characteristics for the delay of the trip The function contains a blocking functionality It is possible to block function outputs timer or the function itself 4 5 1 4 Analog channel configuration PHPTOV has one analog group input which must be properly configured Table 778 Analog inputs Input D...

Page 852: ...the set value of the Start value setting the level detector enables the phase selection logic module The Relative hysteresis setting can be used for preventing unnecessary oscillations if the input signal slightly differs from the Start value setting After leaving the hysteresis area the start condition has to be fulfilled again and it is not sufficient for the signal to only return to the hystere...

Page 853: ...rate time characteristics If the DT characteristics are selected the reset timer runs until the set Reset delay time value is exceeded If the drop off situation exceeds the set Reset delay time the Timer is reset and the START output is deactivated When the IDMT operate time curve is selected the functionality of the Timer in the drop off state depends on the combination of the Type of reset curve...

Page 854: ...ing is applicable only when the IDMT curves are used The Minimum operate time setting should be used with care because the operation time is according to the IDMT curve but always at least the value of the Minimum operate time setting For more information see Chapter 11 3 1 IDMT curves for overvoltage protection in this manual The Timer calculates the start duration value START_DUR which indicates...

Page 855: ...e curve types Operating curve type 5 ANSI Def Time 15 IEC Def Time 17 Inv Curve A 18 Inv Curve B 19 Inv Curve C 20 Programmable 4 5 1 7 Application Overvoltage in a network occurs either due to the transient surges on the network or due to prolonged power frequency overvoltages Surge arresters are used to protect the network against the transient overvoltages but the relay s protection function is...

Page 856: ...Values Range Unit Step Default Description Start value 0 05 1 60 xUn 0 01 1 10 Start value Time multiplier 0 025 15 000 0 005 1 000 Time multiplier in IEC ANSI IDMT curves Operate delay time 40 300000 ms 10 40 Operate delay time Operating curve type 5 ANSI Def Time 15 IEC Def Time 17 Inv Curve A 18 Inv Curve B 19 Inv Curve C 20 Programmable 15 IEC Def Time Selection of time delay curve type Table ...

Page 857: ... 000 Parameter E for customer program mable curve Voltage selection 1 phase to earth 2 phase to phase 2 phase to phase Parameter to select phase or phase to phase voltages Table 787 PHPTOV Non group settings Advanced Parameter Values Range Unit Step Default Description Minimum operate time 40 60000 ms 1 40 Minimum operate time for IDMT curves Reset delay time 0 60000 ms 1 20 Reset delay time Curve...

Page 858: ...cation Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Three phase undervoltage protec tion PHPTUV 3U 27 4 5 2 2 Function block Figure 483 Function block 4 5 2 3 Functionality The three phase undervoltage protection function PHPTUV is used to disconnect from the network devices for example electric motors which are damaged when subjected to serv...

Page 859: ...tart phases is set to 1 out of 3 but the other two channels must be fed with high values considerably above Start value For other values of Num of start phases all three voltage channels must be connected Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the conte...

Page 860: ...d usage of Curve Sat Relative setting see Chapter 11 3 2 IDMT curves for undervoltage protection in this manual The level detector contains a low level blocking functionality for cases where one of the measured voltages is below the desired level This feature is useful when unnecessary starts and operates are wanted to avoid during for example an autoreclose sequence The low level blocking is acti...

Page 861: ... Timer is reset and the START output is deactivated When the IDMT operate time curve is selected the functionality of the Timer in the drop off state depends on the combination of the Type of reset curve Type of time reset and Reset delay time settings Table 792 Reset time functionality when IDMT operation time curve selected Reset functionality Setting Type of reset curve Setting Type of time res...

Page 862: ...ation time is according to the IDMT curve but always at least the value of the Minimum operate time setting For more information see Chapter 11 3 2 IDMT curves for undervoltage protection in this manual The Timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operation time The value is available in the Monitored data view Bloc...

Page 863: ...re caused by abnormal operation or a fault in the power system PHPTUV can be used in combination with overcurrent protections Other applications are the detection of a no voltage condition for example before the energization of a high voltage line or an automatic breaker trip in case of a blackout PHPTUV is also used to initiate voltage correction measures such as insertion of shunt capacitor bank...

Page 864: ...n IEC ANSI IDMT curves Operate delay time 20 300000 ms 10 60 Operate delay time Operating curve type 5 ANSI Def Time 15 IEC Def Time 21 Inv Curve A 22 Inv Curve B 23 Programmable 15 IEC Def Time Selection of time delay curve type Table 797 PHPTUV Group settings Advanced Parameter Values Range Unit Step Default Description Type of reset curve 1 Immediate 2 Def time reset 1 Immediate Selection of re...

Page 865: ...ase Parameter to select phase or phase to phase voltages Table 799 PHPTUV Non group settings Advanced Parameter Values Range Unit Step Default Description Minimum operate time 20 60000 ms 1 60 Minimum operate time for IDMT curves Reset delay time 0 60000 ms 1 20 Reset delay time Curve Sat Relative 0 0 10 0 0 1 0 0 Tuning parameter to avoid curve dis continuities Voltage block value 0 05 1 00 xUn 0...

Page 866: ...n Change PCL4 F New minimum value 20 ms for Operate delay time and Minimum operate time settings 4 5 3 Residual overvoltage protection ROVPTOV ANSI 59G 59N 4 5 3 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Residual overvoltage protection ROVPTOV Uo 59G 59N 1 Start value 0 97 Un voltage level before fault 1 Un fn 50 Hz underv...

Page 867: ...iption URES Residual voltage measured or calculated See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 804 Special conditions Condition Description URES calculated The function requires that all three voltage channels are connected to calculate residu al voltage Setting VT connec...

Page 868: ...the START output is deactivated The timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operation time The value is available in the monitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting in Configuration System Bl...

Page 869: ...used as a backup protection or as a release signal for the feeder earth fault protection The protection can also be used for the earth fault protection of generators and motors and for the unbalance protection of capacitor banks The residual voltage can be calculated internally based on the measurement of the three phase voltage This voltage can also be measured by a single phase voltage transform...

Page 870: ... 811 ROVPTOV Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured voltage fn 2 Hz 1 5 of the set value or 0 002 Un Start time1 2 UFault 2 set Start value Minimum Typical Maximum 48 ms 51 ms 54 ms Reset time Typically 40 ms Reset ratio Typically 0 96 Retardation time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20 ms Suppress...

Page 871: ...with the other protection functions increases the security of the protection system The function starts when the positive sequence voltage exceeds the set limit PSPTOV operates on definite time DT characteristics The function contains a blocking functionality It is possible to block function outputs the definite timer or the function itself 4 5 4 4 Analog channel configuration PSPTOV has one analo...

Page 872: ...er U3P U_A U_B U_C Blocking logic Figure 489 Functional module diagram Level detector The calculated positive sequence voltage is compared to the set Start value setting If the value exceeds the set Start value the level detector enables the timer The Relative hysteresis setting can be used for preventing unnecessary oscillations if the input signal slightly varies from the Start value setting Aft...

Page 873: ...en the voltage to frequency ratio increases much above the design value resulting into transformer operation under a nonlinear region A transformer can be in such an overvoltage situation during a sudden loss of load due to underfrequency load shedding Overexcitation results in an increase of the exciting current which leads to core heating and thus to transformer damage PSPTOV along with the unde...

Page 874: ... group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time Relative hysteresis 1 0 5 0 0 1 4 0 Relative hysteresis for operation 4 5 4 9 PSPTOV Monitored data Table 819 PSPTOV Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time PSPTOV Enum 1 on 2 blocked 3 test 4 ...

Page 875: ...tage protection NSPTOV U2 59NS 4 5 5 2 Function block Figure 490 Function block 4 5 5 3 Functionality The negative sequence overvoltage protection function NSPTOV is used to detect negative sequence overvoltage conditions NSPTOV is used for the protection of machines The function starts when the negative sequence voltage exceeds the set limit NSPTOV operates with the definite time DT characteristi...

Page 876: ...th certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 4 5 5 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The operation of NSPTOV can be described...

Page 877: ...ation A continuous or temporary voltage unbalance can appear in the network for various reasons The voltage unbalance mainly occurs due to broken conductors or asymmetrical loads and is characterized by the appearance of a negative sequence component of the voltage In rotating machines the voltage unbalance results in a current unbalance which heats the rotors of the machines The rotating machines...

Page 878: ... voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode NSPTOV Output signals Table 824 NSPTOV Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start 4 5 5 8 NSPTOV Settings Table 825 NSPTOV Group settings Basic Parameter Values Range Unit Step Default Description Start value 0 010 1 000 xUn 0 001 0 030 Start value Operate delay time 40 120000 ms 1 ...

Page 879: ...ly 40 ms Reset ratio Typically 0 96 Retardation time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20 ms Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 4 5 6 Positive sequence undervoltage protection PSPTUV ANSI 27PS 4 5 6 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Positive sequence...

Page 880: ...s the definite timer or the function itself 4 5 6 4 Analog channel configuration PSPTUV has one analog group input which must be properly configured Table 830 Analog inputs Input Description U3P Three phase voltages See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 831 Special c...

Page 881: ...esired level This feature is useful when unnecessary starts and operates are wanted to avoid during for example an autoreclose sequence The low level blocking is activated by default Enable block value is set to Enabled and the blocking level can be set with the Voltage block value setting Timer Once activated the timer activates the START output The time characteristic is according to DT When the...

Page 882: ...is the probability that the generator loses the synchronism The positive sequence voltage is also available during asymmetrical faults It is a more appropriate criterion for detecting the risk of loss of synchronism than for example the lowest phase to phase voltage Analyzing the loss of synchronism of a generator is rather complicated and requires a model of the generator with its prime mover and...

Page 883: ...ime 40 120000 ms 10 40 Operate delay time Table 835 PSPTUV Group settings Advanced Parameter Values Range Unit Step Default Description Voltage block value 0 01 1 00 xUn 0 01 0 20 Internal blocking level Enable block value 0 False 1 True 1 True Enable Internal Blocking Table 836 PSPTUV Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation...

Page 884: ...ly 40 ms Reset ratio Depends on the set Relative hysteresis Retardation time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20 ms Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 4 5 7 Overexcitation protection OEPVPH ANSI 24 4 5 7 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Overexcitat...

Page 885: ...ains a blocking functionality It is possible to block the function outputs reset timer or the function itself 4 5 7 4 Analog channel configuration OEPVPH has two analog group inputs which must be properly configured Table 840 Analog inputs Input Description I3P Three phase currents U3P Three phase voltages See the preprocessing function blocks in this document for the possible signal sources There...

Page 886: ...E U3P I3P U f calculation I_A I_B I_C I1 U_A_AB U_B_BC U_C_CA U1 F Blocking logic Figure 495 Functional module diagram U f calculation This module calculates the U f ratio that is the excitation level from the internal induced voltage E and frequency The actual measured voltage U m deviates from the internal induced voltage E a value the equipment has to withstand This voltage compensation is base...

Page 887: ... currents are fed to the protection relay the positive sequence alternative is recommended If the leakage reactance of the protected equipment is unknown or if the measured voltage U m is to be used in the excitation level calculation then by setting the leakage reactance value to zero the calculated induced voltage E is equal to the measured voltage The calculated U f ratio is scaled to a value b...

Page 888: ... inverse time curve the OPERATE output is activated In a drop off situation that is when the excitation level drops below Start value before the function operates the reset timer is activated and the START output resets after the time delay of Reset delay time for the DT characteristics For the IDMT curves the reset operation is as described in Chapter 4 5 7 6 Timer characteristics For the IDMT cu...

Page 889: ...s When the DT characteristics are selected the functionality is only affected by the Operate delay time and Reset delay time settings OEPVPH also supports four overexcitation IDMT characteristic curves OvExt IDMT Crv1 OvExt IDMT Crv2 OvExt IDMT Crv3 and OvExt IDMT Crv4 Overexcitation inverse definite minimum time curve IDMT In the inverse time modes the operate time depends on the momentary value ...

Page 890: ...fault reoccurs the integration continues from the current integral value and the start time is adjusted as shown in Figure 496 The start time becomes the value at the time when the fault dropped off minus the amount of reset time that occurred If the reset period elapses without a fault being detected the saved values of the start time and integration are cleared Figure 496 An example of a delayed...

Page 891: ...nt IDMT curves Operating curve type setting a b c OvExt IDMT Crv1 2 5 115 00 4 886 OvExt IDMT Crv2 2 5 113 50 3 040 OvExt IDMT Crv3 2 5 108 75 2 443 Figure 497 Operating time curves for the overexcitation IDMT curve OvExt IDMT Crv1 for parameters a 2 5 b 115 0 and c 4 886 Overexcitation IDMT curve 4 The base equation for the IDMT curve OvExt IDMT Crv4 is 1MRS759142 F Protection functions REX640 Te...

Page 892: ... output activates the BLK_RESTART output If the excitation level increases above the set value when BLK_RESTART is active the OPERATE output is activated immediately If the excitation level increases above the set value when BLK_RESTART is not active but COOL_ACTIVE is active the OPERATE output is not activated instantly In this case the remaining part of the cooling timer affects the calculation ...

Page 893: ...ed on the design The greatest risk for overexcitation exists in a thermal power station when the generator transformer unit is disconnected from the rest of the network or in the network islands where high voltages or low frequencies can occur Overexcitation can occur during the start up and shutdown of the generator if the field current is not properly adjusted The loss of load or load shedding c...

Page 894: ...ion protection Example 1 Nominal values of the machine Nominal phase to phase voltage U n 11000 V Nominal phase current I n 7455 A Nominal frequency f n 50 Hz Leakage reactance X leak 20 or 0 2 pu Measured voltage and load currents of the machine Phase A to phase B voltage U AB 11500 0 V Phase A current I A 5600 63 57 A Phase B current I B 5600 176 42 A Measured frequency f m 49 98 Hz The setting ...

Page 895: ...e value 100 percent for the setting Voltage Max Cont is recommended If the Voltage Max Cont setting is 105 percent the excitation level M of the machine is calculated with the equation Excitationlevel M 12490 49 98 11000 50 1 05 1 0818 Equation 254 Example 3 In this case the function operation is according to IDMT The Operating curve type setting is selected as OvExt IDMT Crv2 The corresponding ex...

Page 896: ... Maximum operate time setting limits the operate time to 1000 s if the excitation level stays between 1 1 and 1 16 In general however the excitation level seldom remains constant Therefore the exact operate times in any inverse time mode are difficult to predict Example 4 In this case the function operation is according to IDMT The Operating curve type setting is selected as OvExt IDMT Crv4 The co...

Page 897: ...ld be 5 90 s as per the two dots in Figure 501 In this case the setting Maximum operate time 3600 s does not limit the maximum operate time because the operate time at Start value 110 1 1 pu is approximately 75 s 4 5 7 8 Signals OEPVPH Input signals Table 844 OEPVPH Input signals Name Type Default Description I3P SIGNAL Three phase currents U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Blo...

Page 898: ...ltiplier 0 1 100 0 0 1 3 0 Time multiplier for Overexcitation IDMT curves Operate delay time 200 200000 ms 10 500 Operate delay time in definite time mode Table 847 OEPVPH Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Mode Off On Cooling time 5 10000 s 1 600 Time required to cool the machine Constant delay 100 120000 ms 10 800 Par...

Page 899: ...ription START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time in T_ENARESTART INT32 0 10000 s Estimated time to reset of block restart VOLTPERHZ FLOAT32 0 00 10 00 pu Excitation level i e U f ratio or Volts Hertz OEPVPH Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 5 7 11 Technical data Table 850 OEPVPH Technical data Characteristic Value Operation accuracy Depending on the fr...

Page 900: ...ree phase undervoltage protection PHPTUV by allowing the grid operators to define its own Low Voltage Ride Through LVRT curve for generators as defined by local or national grid codes The LVRT curve can be defined accurately according to the requirements by setting the appropriate time voltage coordinates This function contains a blocking functionality LVRTPTUV can be blocked with the BLOCK input ...

Page 901: ...g starts with detection of undervoltage Undervoltage detection depends on Voltage selection setting All selectable options are based on fundamental frequency components Function uses phase to earth voltages when Voltage selection is set to Highest Ph to E or Lowest Ph to E and phase to phase voltages when Voltage selection is set to Highest Ph to Ph or Lowest Ph to Ph When the Voltage selection se...

Page 902: ...ion has elapsed that is START output remains active LVRT curve is defined using time voltage settings coordinates The settings available are Recovery time 1 Recovery time 10 and Voltage level 1 Voltage level 10 The number of coordinates required to define a LVRT curve is set by Active coordinate settings When Recovery time 1 is set to non zero value it results into horizontal characteristics from ...

Page 903: ... 4 0 9 Un Recovery time 4 1500 ms Voltage level 5 0 9 Un Recovery time 5 3000 ms It is necessary that the last active Voltage level X setting is set greater than or equal to Voltage start value Settings are not accepted if the last active Voltage level X setting is not set greater than or equal to Voltage start value Figure 506 describes an example of operation of LVRTPTUV protection function set ...

Page 904: ...tage frequency regulation These requirements make it necessary for the wind and solar farms to remain in operation in the event of network disturbances Many grid codes now demand that the distributed generation connected to HV grids must withstand voltage dips to a certain percentage of nominal voltage down to 0 in some cases and for a specific duration Such requirements are known as Low Voltage R...

Page 905: ...es below the curve Figure 507 A typical required ride through voltage capability of generating unit The LVRT requirement depends on the power system characteristics and the protection employed varying significantly from each other The requirement also differs from country to country LVRTPTUV function incorporates four types of LVRT curves which satisfy most of the power system needs Grid operators...

Page 906: ...meter to select voltage for curve monitoring Active coordinates 1 10 1 3 Coordinates used for defining LVRT curve Voltage level 1 0 00 1 20 xUn 0 01 0 20 1st voltage coordi nate for defining LVRT curve Voltage level 2 0 00 1 20 xUn 0 01 0 80 2nd voltage coordi nate for defining LVRT curve Voltage level 3 0 00 1 20 xUn 0 01 0 90 3rd voltage coordi nate for defining LVRT curve Voltage level 4 0 00 1...

Page 907: ... 6 0 300000 ms 1 10000 6th time coordinate for defining LVRT curve Recovery time 7 0 300000 ms 1 10000 7th time coordinate for defining LVRT curve Recovery time 8 0 300000 ms 1 10000 8th time coordinate for defining LVRT curve Recovery time 9 0 300000 ms 1 10000 9th time coordinate for defining LVRT curve Recovery time 10 0 300000 ms 1 10000 10th time coordi nate for defining LVRT curve 4 5 8 9 LV...

Page 908: ...continuously the duration of a voltage cycle At the instance of islanding the duration of measured voltage cycle becomes shorter or longer than the previous one that is the measured voltage cycle shifts with time This shifting of voltage is measured in terms of phase angle VVSPPAM issues an instantaneous trip when the shift in voltage vector exceeds the set value VVSPPAM can be blocked with BLOCK ...

Page 909: ...BLKD U3P Vector shift detector U_A_AB U_B_BC U_C_CA Pulse timer Figure 509 Functional module diagram Vector shift detector This module measures the duration of each cycle of the voltage signal phase The duration of the present cycle is compared to the previous cycle considered as reference When the mains is lost a sudden change is seen in the cycle length if loading of the generator changes sudden...

Page 910: ...he Pulse timer is activated it activates the OPERATE output The pulse length of OPERATE is fixed to 100 ms The activation of the BLOCK input deactivates the OPERATE binary output and resets the timer 4 5 9 6 Application Use of distributed generation DG units is increasing due to liberalized markets deregulation and the global trend to use more renewable sources of energy They generate power in the...

Page 911: ... distributed generation units is nearly balanced for example if the power mismatch or unbalance is less than 5 10 with the active and reactive power consumed by loads a large enough voltage phase shift may not occur which can be detected by the vector shift algorithm This means that the vector shift algorithm has a small non detection zone NDZ which is also dependent on the type of generators load...

Page 912: ...AN Operate INT_BLKD BOOLEAN Protection function internally blocked 4 5 9 8 VVSPPAM Settings Table 864 VVSPPAM Group settings Basic Parameter Values Range Unit Step Default Description Start value 2 0 30 0 deg 0 1 6 0 Start value for vec tor shift Table 865 VVSPPAM Group settings Advanced Parameter Values Range Unit Step Default Description Over Volt Blk value 0 40 1 50 xUn 0 01 1 20 Voltage above ...

Page 913: ... BC VEC_SHT_C_CA FLOAT32 180 00 180 00 deg Vector shift for phase to earth voltage C or phase to phase voltage CA VEC_SHT_U1 FLOAT32 180 00 180 00 deg Vector shift for positive sequence voltage VVSPPAM Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 5 9 10 Technical data Table 869 VVSPPAM Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured vol...

Page 914: ... voltage exceeds the set limit PHVPTOV operates with the definite time DT characteristics The function contains a blocking functionality It is possible to block function outputs the definite timer or the function itself 4 5 10 4 Analog channel configuration PHVPTOV has one analog group input which must be properly configured Table 870 Analog inputs Input Description U3P Three phase voltages See th...

Page 915: ...for each of the three input phase voltages The calculation is done in three successive aggregations 10 12 cycle voltage input samples are aggregated to calculate the 10 12 cycle RMS voltage 10 12 cycle RMS voltages are aggregated over a time period of Trefresh to get the refresh value Refresh values are aggregated over a time period Taverage to get the average RMS voltage magnitude The Voltage sel...

Page 916: ...initialization of the function the average voltage is calculated considering initial values as zero On the IEC 61850 mapped data the quality of the calculated average voltage value is indicated as Questionable until the first complete time interval passes The calculated average voltage measurement for the set Time interval for all three phase to earth and phase to phase voltages U_MEAN_A U_MEAN_B ...

Page 917: ... the module operates the reset timer is activated The timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operating time The value is available in the monitored data view When the relay has tripped due to variation overvoltage protection check that operation is safe before closing the breaker Clear the average voltage value by...

Page 918: ...low voltage variation using 10 min mean RMS value CEI EN 50160 standard indicates that the RMS value of the voltage calculated over a period of 10 min should not exceed 110 of the nominal voltage if the voltage exceeds this level the generator must be disconnected from the network within 3 s PHVPTOV provides overvoltage protection by calculating the RMS value over a period of 10 min A sudden chang...

Page 919: ... voltages Table 876 PHVPTOV Non group settings Advanced Parameter Values Range Unit Step Default Description Relative hysteresis 1 0 5 0 0 1 4 0 Relative hysteresis for operation 4 5 10 9 PHVPTOV Monitored data Table 877 PHVPTOV Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Ratio of start time op erate time U_MEAN_A FLOAT32 0 00 5 00 xUn Mean value of phase t...

Page 920: ...ication ANSI IEEE C37 2 device number Frequency protection FRPFRQ f f df dt 81 4 6 1 2 Function block Figure 513 Function block 4 6 1 3 Functionality The frequency protection function FRPFRQ is used to protect network components against abnormal frequency conditions The function provides basic overfrequency underfrequency and frequency rate of change protection Additionally it is possible to use c...

Page 921: ...og channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 4 6 1 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding paramet...

Page 922: ...c This module is used for combining different protection criteria based on the frequency and the frequency gradient measurement to achieve a more sophisticated behavior of the function The criteria are selected with the Operation mode setting Table 881 Operation modes for operation logic Operation mode Description Freq The function operates independently as the underfrequency Freq protection funct...

Page 923: ...ivates the START and STR_FRG outputs The time characteristic is according to DT When the operation timer has reached the value set by the Operate Tm df dt setting the OPERATE and OPR_FRG outputs are activated If the frequency gradient restores before the module operates the reset timer is acti vated If the timer reaches the value set by the Reset delay Tm df dt setting the operate timer resets and...

Page 924: ...ts set value A detailed information from the active module is avail able at the STR_OFRQ and STR_FRG outputs The shortest operate delay time from the set Operate Tm Freq or Oper ate Tm df dt is dominant regarding the OPERATE output The time characteristic is according to DT The characteristic that activates the OPERATE output can be seen from the OPR_OFRQ or OPR_FRG output If the frequency gradien...

Page 925: ...ur due to a sudden loss of a significant amount of load or due to failures in the turbine governor system If the situation continues and escalates the power system loses its stability The underfrequency is applicable in all situations where a reliable detection of a low fundamental power system voltage frequency is needed The low fundamental frequency in a power system indicates that the generated...

Page 926: ...ST_OFRQ BOOLEAN Start signal for overfrequency ST_UFRQ BOOLEAN Start signal for underfre quency ST_FRG BOOLEAN Start signal for frequency gradient 4 6 1 8 FRPFRQ Settings Table 885 FRPFRQ Group settings Basic Parameter Values Range Unit Step Default Description Operation mode 1 Freq 2 Freq 3 df dt 4 Freq df dt 5 Freq df dt 6 Freq OR df dt 7 Freq OR df dt 1 Freq Frequency protec tion operation mode...

Page 927: ... 1 0 Reset delay time for frequency Reset delay Tm df dt 0 60000 ms 1 0 Reset delay time for rate of change 4 6 1 9 FRPFRQ Monitored data Table 888 FRPFRQ Monitored data Name Type Values Range Unit Description START_DUR FLOAT32 0 00 100 00 Start duration ST_DUR_OFRQ FLOAT32 0 00 100 00 Start duration ST_DUR_UFRQ FLOAT32 0 00 100 00 Start duration ST_DUR_FRG FLOAT32 0 00 100 00 Start duration FRPFR...

Page 928: ...d shedding and restoration LSHDPFRQ UFLS R 81LSH 4 6 2 2 Function block Figure 515 Function block 4 6 2 3 Functionality The load shedding and restoration function LSHDPFRQ is capable of performing load shedding based on underfrequency and the rate of change of the frequency The load that is shed during the frequency disturbance can be restored once the frequency has stabilized to the normal level ...

Page 929: ... 4 Analog channel configuration LSHDPFRQ has one analog group input which must be properly configured Table 891 Analog inputs Input Description U3P Three phase voltages See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 892 Special conditions Condition Description U3P connected t...

Page 930: ...n timer activates the ST_FRQ output When the underfrequency timer has reached the value set by Operate Tm Freq the OPR_FRQ output is activated if the underfrequency condition still persists If the frequency becomes normal before the module operates the reset timer is activated If the reset timer reaches the value set by Reset delay time the timer resets and the ST_FRQ output is deactivated df dt d...

Page 931: ...r resets and the ST_FRG output is deactivated Load shedding control The way of load shedding that is whether to operate based on underfrequency or high df dt or both is defined with the Load shed mode user setting The valid operation modes for the Load shed mode settings are Freq Freq AND df dt and Freq OR df dt Once the selected operation mode conditions are satisfied the START and OPERATE output...

Page 932: ...FRG 500ms 1s OPERATE is activated as Freq AND df dt condition satisfied OPERATE 48 75 Hz Start of operation timer ST_FRQ OPR_FRQ Start of operation timer 1s Time s Frequency Hz Figure 517 Load shedding operation in the Freq AND df dt mode when both Freq and df dt conditions are satisfied Rated frequency 50 Hz Protection functions 1MRS759142 F 932 REX640 Technical Manual ...

Page 933: ...ode Description Disabled Load restoration is disabled Auto In the Auto mode input frequency is continuously compared to the Restore start Val setting The restore detection module includes a timer with the DT characteristics Upon detection of restoring the operation timer activates the ST_REST output When the timer has reached the value of the Restore delay time setting the RESTORE output is activa...

Page 934: ...reeze timers mode the operate timer is frozen to the prevailing value but the OPERATE output is not deactivated when blocking is activated In the Block all mode the whole function is blocked and the timers are reset In the Block OPERATE output mode the function operates normally but the OPERATE OPR_FRQ and OPR_FRG outputs are not activated 4 6 2 6 Application An AC power system operates at a defin...

Page 935: ... required to be deployed at various places near the load centers A quick shedding of a large amount of load from one place can cause a significant disturbance in the system The load shedding scheme can be made most effective if the shedding of load feeders is distributed and discrete that is the loads are shed at various locations and in distinct steps until the system frequency reaches the accept...

Page 936: ... are taken only if necessary In order to take the effect of any transient a sufficient time delay should be set The value of the setting has to be well below the lowest occurring normal frequency and well above the lowest acceptable frequency of the system The setting level the number of steps and the distance between two steps in time or in frequency depend on the characteristics of the power sys...

Page 937: ...evere disturbances in large power systems the rate of change of the frequency is much less often just a fraction of 1 0 Hz s Similarly the setting for df dt can be from 0 1 Hz s to 1 2 Hz s in steps of 0 1 Hz s to 0 3 Hz s for large distributed power networks with the operating time varying from a few seconds to a few fractions of a second Here the operating time should be kept in minimum for the ...

Page 938: ...E BOOLEAN Operation of load shedding OPR_FRQ BOOLEAN Operate signal for under fre quency OPR_FRG BOOLEAN Operate signal for high df dt START BOOLEAN Start ST_FRQ BOOLEAN Pick Up signal for under fre quency detection ST_FRG BOOLEAN Pick Up signal for high df dt detection RESTORE BOOLEAN Restore signal for load restor ing purposes ST_REST BOOLEAN Restore frequency attained and restore timer started ...

Page 939: ...0000 ms 10 300 Time delay to re store Table 899 LSHDPFRQ Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 900 LSHDPFRQ Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 50 Time delay after which the definite timers will reset 4 6 2 9 LSHDPFRQ Monitored data Tab...

Page 940: ...onnectivity level Technical revision Change PCL2 E Changed the Start value Freq and Restore start Val steps to 0 0001 xFn 4 7 Impedance protection 4 7 1 Distance protection DSTPDIS ANSI 21P 21N 4 7 1 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Distance protection DSTPDIS Z 21P 21N 4 7 1 2 Function block Figure 520 Function b...

Page 941: ...s Load encroachment area Figure 521 Zones of DSTPDIS function example 1 ZL Zone Z1 Zone Z5 Zone Z2 Zone Z3 X R Zon Z4 Under impedance start characteristics Load encroachment area e Figure 522 Zones of DSTPDIS function example 2 The supported zone characteristic shapes are quadrilateral mho circular or bullet quadrilateral and mho characteristics combined Mho can be combined with directional lines ...

Page 942: ...ment polarization if the corresponding voltage drops too low DSTPDIS has separate and independent measurement elements for each fault loop in the distance protection zone In addition to the full scheme design the separate measuring elements are used for general fault detection and faulted phase selection DSTPDIS supports both fault detection dependent control of zone timers and zone dedicated phas...

Page 943: ...R curves presented in Figure 524 were obtained using the static power outputs SPOs and with Zone timer mode common 4 7 1 4 Analog channel configuration DSTPDIS has five analog group inputs which must be properly configured Table 904 Analog inputs Input Description I3P Three phase currents I3P_PAR 1 Three phase currents Necessary when Par line Comp zone x is set to True I3P_REF 2 Three phase curren...

Page 944: ...ltage channels connected but it is recom mended to connect all three voltage chan nels Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protect...

Page 945: ...but the OPERATE_Z1 5 output is not deactivated when blocking is activated In the Block all mode the whole function is blocked and the timers are reset In the Block OPERATE output mode the function operates normally but the OPERATE_Z1 5 output is not activated In addition the function has zone specific blocking signals BLOCK_Z1 5 The signal resets zone timers disabling the corresponding start and o...

Page 946: ...takes the CT saturation into account with additional stabilization settings Gnd Op current 2 GFC A Ph Stab value GFC and Stab slope 2 GFC Setting EF Cur stabilization to False disables the stabilization of the residual current measurement and should be used only when the residual current is measured with a cable current transformer The residual current threshold setting for earth fault detection i...

Page 947: ... GFC Max phase angle GFC maximum torque line Chr angle GFC 45 deg FORW ARD UNKNOW N UNKNOW N REVERSE Figure 527 Characteristic of the directional function for earth faults The Chr angle GFC setting also known as relay characteristic angle or basic angle is used to turn the directional characteristic It has a positive value when the operating quantity lags the polarizing quantity and a negative val...

Page 948: ...transformer configurations or constructions are not suitable for polarization In case of dual polarization Zro vol OR cur the zero sequence voltage polarization and zero sequence current polarization elements are logically OR ed Typically when I0 is high U0 is low and when I0 is low U0 is high Hence the protection can benefit from both elements as the two polarization methods complement each other...

Page 949: ...ing loops can be released for measurement The release of phase to earth fault measuring elements is then blocked RELEASE_PE No fault The operation of the faulted phase selection function is highly dependent on the earth fault detection function The phase preference or faulted loop selection logic can be set to filter the faulted phases to be released for measurement in the protection zones The gen...

Page 950: ...ed phases It can be used in applications where the fault current magnitude exceeds the load current despite the possible changes in the network configuration and fault type In the overcurrent based faulted phase selection method the amplitude of each phase current is compared to the Str A Ph Sel GFC threshold setting If the phase current magnitude exceeds the value of Str A Ph Sel GFC that particu...

Page 951: ...tion the voltage dependent overcurrent method The Voltdep overcur method combines the overcurrent and undervoltage conditions The phase current amplitude is compared to the Str A Ph Sel GFC threshold setting but a lower current Lo A Ph Sel GFC threshold is valid during an undervoltage condition This increases the sensitivity of the fault detection The amplitude of phase to earth and phase to phase...

Page 952: ...IA EARTH_FLT TRUE AG Fault AG Fault No fault IB UB EARTH_FLT IB EARTH_FLT TRUE BG Fault BG Fault No fault IC UC EARTH_FLT IC EARTH_FLT TRUE CG Fault CG Fault No fault IA IB UAB IA IB TRUE AB Fault No fault AB Fault IB IC UBC IB IC TRUE BC Fault No fault BC Fault IC IA UCA IC IA TRUE CA Fault No fault CA Fault IA IB UAB EARTH_FLT IA IB EARTH_FLT TRUE AB Fault AB Fault AB Fault IB IC UBC EARTH_FLT T...

Page 953: ...ed phase selection the underimpedance method The Under impedance and OC AND Und impedance methods use fault loop impedance for identifying the faulted phases The advantage of the underimpedance criterion is that the sensitivity of the fault detection is independent of the source impedance The underimpedance function has six impedance measuring elements The phase to earth measuring elements are cal...

Page 954: ... set the reactive reaches independently in forward and in reverse direction and for phase to earth Gnd and phase to phase PP measurement elements for example the X Gnd Fwd reach GFC X Gnd Rv reach GFC X PP Fwd reach GFC and X PP Rv reach GFC settings Also the resistive reach in case of quadrilateral characteristic can be set both forward and reverse independently of reactive reaches for example th...

Page 955: ...ristics R X X Gnd Fwd reach GFC X Gnd Rv reach GFC R X Angle load area GFC Ris Fwd Rch load GFC Fault detected Fault detected Angle load area GFC Ris Gnd Fwd Rch GFC Ris Gnd Rv Rch GFC Ris Rv Rch load GFC Figure 530 Quadrilateral underimpedance characteristics Table 914 Conversion from element start to monitored data signals Start of element START_GFC STARTS_GF C RELEASE_P E RELEASE_P P ZA EARTH_F...

Page 956: ...magnitude of the fault current through earth can be as high as in the case of a two phase short circuit fault The protection must therefore remove the cross country fault quickly without sacrificing the selectivity This can be done with a phase preference logic which is activated by the cross country fault detection function The phase preference logic transforms the fault into an ordinary single p...

Page 957: ...PP voltage XC GFC U U OR System grounding GFC High impedance System grounding GFC From input SYS_EARTHING TRUE AND OR Figure 531 Cross country fault detection logic for high impedance earthed networks Phase preference logic for high impedance earthed networks The phase preference logic is applicable only in isolated and high impedance earthed networks The phase preference logic for high impedance ...

Page 958: ...he cross country fault cannot be detected as the residual current does not flow through relay R1 The phase to phase loop AB is measured in the forward direction but the estimated impedance represents an average impedance between two fault locations and therefore is not seen in zone Z1 R2 The cross country fault is detected as a high residual current flows through relay R2 Phase A earth fault is se...

Page 959: ...C A EARTH_FLT RELEASE_PE RELEASE_PP 1 No filter AB Fault BC Fault CA Fault AB Fault BC Fault CA Fault 2 No preference No fault No fault No fault AB Fault BC Fault CA Fault 3 Cyc A B C A No fault No fault No fault AB Fault BC Fault CA Fault 4 Cyc A C B A No fault No fault No fault AB Fault BC Fault CA Fault 5 Acyc A B C No fault No fault No fault AB Fault BC Fault CA Fault 6 Acyc A C B No fault No ...

Page 960: ...igure 533 Two phase to earth fault in low impedance earthed system Impedance can be measured during a two phase to earth fault when the earth faults are located in the same direction and they are in close proximity to each other Generally too large an impedance is measured for the lagging phase to earth loop for example phase B in an AB E fault Similarly low impedance is measured for the leading p...

Page 961: ...fault AG Fault CG Fault Table 919 Supported faulted loop phase selection schemes for low impedance earthed networks and their influence on the RELEASE_PP monitored data Ph Prf mode Lo Z GFC Element start All loops PE only PP only BLK leading PE BLK lagging PE RELEASE_PP A B EARTH_FLT AB Fault No fault AB Fault AB Fault AB Fault B C EARTH_FLT BC Fault No fault BC Fault BC Fault BC Fault C A EARTH_F...

Page 962: ...ognized fault type the release signals are given for the corresponding measuring elements DSTPDIS supports both fault detection dependent control of zone timers and zone dedicated timer control for maximum application flexibility Zone dedicated timer control is enabled when configuration parameter Zone timer mode is set to Independent change requires relay reboot In this case operate delay timers ...

Page 963: ... Fault However three phase fault indication for GFC depends also on the additional condition for voltage see Table 913 Table 920 STARTS_Zx information Value Value information 5 No zone starts 1 AG Fault 2 BG Fault 3 AG Fault BG Fault 4 CG Fault 5 AG Fault CG Fault 6 BG Fault CG Fault 7 AG Fault BG Fault CG Fault 8 AB Fault 9 AG Fault AB Fault 10 BG Fault AB Fault 11 AG Fault BG Fault AB Fault 12 C...

Page 964: ...AG Fault BC Fault CA Fault 50 BG Fault BC Fault CA Fault 51 AG Fault BG Fault BC Fault CA Fault 52 CG Fault BC Fault CA Fault 53 AG Fault CG Fault BC Fault CA Fault 54 BG Fault CG Fault BC Fault CA Fault 55 AG Fault BG Fault CG Fault BC Fault CA Fault 56 AB Fault BC Fault CA Fault 57 AG Fault AB Fault BC Fault CA Fault 58 BG Fault AB Fault BC Fault CA Fault 59 AG Fault BG Fault AB Fault BC Fault C...

Page 965: ...e phase to earth impedance measuring elements provide the basic earth fault protection in direct or low impedance earthed networks The earth fault protection is enabled with the setting Op Mod Gnd loops Znx x 1 5 True The enabling requires that all three phase to earth voltages are measured Otherwise the release of the earth fault measuring elements is automatically blocked The reach of phase to e...

Page 966: ...n in use Figure 538 Operation principle of load compensation functionality When three phase feeders are placed close to each other a mutual inductive zero sequence coupling of the current path exists This has an impact during earth faults If no measures are taken this leads to errors in the impedance calculation The residual current of the parallel line induces a voltage in the protection line and...

Page 967: ...on time delay is defined with the Gnd operate Dl Znx x 1 5 setting The timer can be disabled with the Gnd Op Dl mode Znx False setting This blocks the OPERATE_Zx x 1 5 output of the phase to earth measuring elements Phase to phase impedance measuring elements The phase to phase distance protection is suitable as a basic protection function against two phase short circuit faults in various networks...

Page 968: ...ined with the setting PP operate delay Znx x 1 5 The timer can be disabled with the setting PP Op delay Mod Znx False This blocks the OPERATE_Zx x 1 5 output of the phase to phase measuring elements Three phase impedance measuring element DSTPDIS has a dedicated measuring element for a three phase short circuit fault for each zone The three phase measuring element uses the positive sequence quanti...

Page 969: ...be disabled with the setting PP Op delay Mod Znx False This blocks the OPERATE_Zx x 1 5 output of the three phase measuring elements Entering the line reach The line reach is entered in primary ohms The impedance format is selected with Impedance mode Zn Rectangular for the vectors R X and Polar for the magnitude and angle Impedance mode Zn Rectangular In case of phase to phase or three phase impe...

Page 970: ...zone x X0 zone x 3 2 R1 zone x R0 zone x 3 Figure 543 Settings which define the line reach for phase to earth impedance measuring elements if Impedance mode Zn Rectangular forward or reverse directionality In case of non directional characteristics the reactive reach in reverse direction is defined with the X1 reverse zone x x 1 5 setting The total reactive reach in reverse direction includes a pa...

Page 971: ...of non directional characteristics the reactive reach magnitude in reverse direction is defined with the Z1 reverse zone x x 1 5 setting The characteristic line angle Z1 angle zone x is the same for forward and reverse direction X R Forward X R Reverse X R Non directional Z1 angle zone x Z1 angle zone x Z1 angle zone x Z1 angle zone x Z 1 r e v e r s e z o n e x Z 1 z o n e x Z 1 z o n e x Z 1 z o...

Page 972: ... Forward X R Reverse X R Non directional α α α α Figure 546 Settings which define the line reach for phase to earth impedance measuring elements if Impedance mode Zn Polar Protection zone characteristics DSTPDIS has both Quadrilateral and Mho circular characteristics available for the protection zones and they can be combined also with the bullet characteristic The shape of a tripping characterist...

Page 973: ...h is defined at the minimum and maximum resistive reach with settings Min Ris Gnd Rch Znx Max Ris Gnd Rch Znx Min Ris PP Rch Znx Max Ris PP Rch Znx x 1 5 In case of a non directional zone only settings Min Ris Gnd Rch Znx and Min Ris PP Rch Znx x 1 5 are valid The resistive reach can be set independently for phase to earth and for phase to phase or three phase elements In case of phase to earth im...

Page 974: ...ield Description MSB xx xx xx xx YZ LSB Y active Zone 1 earth fault impedance ele ment tilt angle modified Z active Zone 1 short circuit impedance ele ment tilt angle modified MSB xx xx xx YZ zz LSB Y active Zone 2 earth fault impedance ele ment tilt angle modified Z active Zone 2 short circuit impedance ele ment tilt angle modified MSB xx xx YZ xx xx LSB Y active Zone 3 earth fault impedance ele ...

Page 975: ... volt Max phase angle zone Min phase angle zone Forward Max phase angle zone Min phase angle zone Reverse X R X R Directional mode Znx Reverse Directional mode Znx Forward Figure 549 Settings that adjust directional lines in case of quadrilateral characteristics The calculated direction of the fault or load if there is no fault present current is indicated for each zone with outputs DIRECTION_Z1 Z...

Page 976: ...racteristic is an exception as it is independent of the selected polarization method It is always explicitly defined by the reach settings and thus fixed in the impedance plane Table 922 Polarization methods and corresponding polarization voltages Fault loop Self pol Cross pol Pos seq volt ZA UL1 j UL23 3 U1 ZB UL2 j UL31 3 U1 1 120 ZC UL3 j UL23 3 U1 1 120 ZAB UL12 j UL23 UL31 3 U1 3 1 30 ZBC UL2...

Page 977: ... fault the circle expands as a function of source impedance and earthing impedance magnitudes Z1source Z0source 3 ZE Phase to phase three phase X R Z1source 2 Z1Line X R Phase to Earth Z1source Z0source 3 ZE 2 Z1Line Z0Line 3 Figure 551 Tripping characteristic in case the zone characteristic is Mho circular and Pol quantity zone is Pos seq volt One alternative for polarization is also Self pol des...

Page 978: ...istic for phase to earth impedance measuring elements if Impedance Chr GND Zn is Mho circular and Directional mode Znx is Non directional On the left Impedance mode Zn is Rectangular On the right Impedance mode Zn is Polar Adding of directional lines into circular mho characteristic Directional lines which are always included in the directional quadrilateral characteristic can also be included in ...

Page 979: ...quantity zone Cross pol Pos seq volt Self pol Bullet combi characteristic If the impedance zone shape equals Bullet combi the distance protection has a tripping characteristic which is a combination of the quadrilateral and mho All settings relevant to the quadrilateral and mho are applicable The shape of the Bullet combi characteristic is affected by the selected polarization method of the mho ci...

Page 980: ...ult 1 2 and 3 Data bank Fault 1 holds the most recent recorded data and the older data is moved into the following banks 1 2 and 2 3 when triggering occurs When all three banks have data and a new triggering occurs the latest data is placed into bank 1 and the data in bank 3 is overwritten by the data from bank 2 Table 923 Recorded data for the phase selection function Parameter name Description T...

Page 981: ... 5 Zones 1 and 3 6 Zones 2 and 3 7 Zones 1 2 and 3 8 Zone 4 9 Zones 1 and 4 10 Zones 2 and 4 11 Zones 1 2 and 4 12 Zones 3 and 4 13 Zones 1 3 and 4 14 Zones 2 3 and 4 15 Zones 1 2 3 and 4 16 Zone 5 17 Zones 1 and 5 18 Zones 2 and 5 19 Zones 1 2 and 5 20 Zones 3 and 5 21 Zones 1 3 and 5 22 Zones 2 3 and 5 23 Zones 1 2 3 and 5 24 Zones 4 and 5 25 Zones 1 4 and 5 Table continues on the next page 1MRS...

Page 982: ...ne Zx Phase reactance Znx Phase reactance Znx In case of a no fault condition the direction of the load current seen by a three phase fault measuring element based on positive sequence signal data is indicated DIR_LOOP_R and DIR_LOOP_X are the loop resistance and reactance from the impedance calculation used in directional discrimination for zone 1 Depending on the released fault loops the calcula...

Page 983: ...ed schemes In these networks DSTPDIS is used to provide a fast and selective protection for overhead lines and power cables It can also be applied for radial feeders to increase the sensitivity of the protection especially if the short circuit power of the source is low or it changes due to network operation From the selectivity point of view it is advantageous that in the protection chain all fun...

Page 984: ... and three phase faults in various networks regardless of the treatment of the neutral point The independent setting of the reach in the reactive and the resistive directions makes it possible to create a fast and selective short circuit protection in many applications 4 7 1 8 Signals DSTPDIS Input signals Table 926 DSTPDIS Input signals Name Type Default Description I3P SIGNAL Three phase current...

Page 985: ...gnal zone 3 START_Z4 BOOLEAN General start signal zone 4 START_Z5 BOOLEAN General start signal zone 5 XC_FLT BOOLEAN Indication of a cross country fault high imp earthed GFC DIRECTION_Z1 Enum Direction of fault or load zone 1 DIRECTION_Z2 Enum Direction of fault or load zone 2 DIRECTION_Z3 Enum Direction of fault or load zone 3 DIRECTION_Z4 Enum Direction of fault or load zone 4 DIRECTION_Z5 Enum ...

Page 986: ...d reach for PE loops underimpedance PSL X Gnd Rv reach GFC 0 00 3000 00 ohm 0 01 40 00 Reactive reverse reach for PE loops underimpedance PSL Ris Gnd Fwd Rch GFC 0 00 500 00 ohm 0 01 100 00 Resistive forward reach for PE loops underimpedance PSL Ris Gnd Rv Rch GFC 0 00 500 00 ohm 0 01 100 00 Resistive reverse reach for PE loops underimpedance PSL X PP Fwd reach GFC 0 00 3000 00 ohm 0 01 40 00 Reac...

Page 987: ...1 zone 1 0 00 3000 00 ohm 0 01 40 00 Positive sequence resistive reach zone 1 X1 zone 1 0 00 3000 00 ohm 0 01 40 00 Positive sequence reactive reach zone 1 X1 reverse zone 1 0 00 3000 00 ohm 0 01 40 00 Pos seq reactive reach in rev dir non dir zone 1 Z1 zone 1 0 01 3000 00 ohm 0 01 56 57 Positive sequence reach zone 1 Z1 angle zone 1 15 0 90 0 deg 0 1 45 0 Positive sequence line angle zone 1 Z1 re...

Page 988: ...one 2 0 00 3000 00 ohm 0 01 40 00 Positive sequence resistive reach zone 2 X1 zone 2 0 00 3000 00 ohm 0 01 40 00 Positive sequence reactive reach zone 2 X1 reverse zone 2 0 00 3000 00 ohm 0 01 40 00 Pos seq reactive reach in rev dir non dir zone 2 Z1 zone 2 0 01 3000 00 ohm 0 01 56 57 Positive sequence reach zone 2 Z1 angle zone 2 15 0 90 0 deg 0 1 45 0 Positive sequence line angle zone 2 Z1 rever...

Page 989: ...one 3 0 00 3000 00 ohm 0 01 40 00 Positive sequence resistive reach zone 3 X1 zone 3 0 00 3000 00 ohm 0 01 40 00 Positive sequence reactive reach zone 3 X1 reverse zone 3 0 00 3000 00 ohm 0 01 40 00 Pos seq reactive reach in rev dir non dir zone 3 Z1 zone 3 0 01 3000 00 ohm 0 01 56 57 Positive sequence reach zone 3 Z1 angle zone 3 15 0 90 0 deg 0 1 45 0 Positive sequence line angle zone 3 Z1 rever...

Page 990: ...one 4 0 00 3000 00 ohm 0 01 40 00 Positive sequence resistive reach zone 4 X1 zone 4 0 00 3000 00 ohm 0 01 40 00 Positive sequence reactive reach zone 4 X1 reverse zone 4 0 00 3000 00 ohm 0 01 40 00 Pos seq reactive reach in rev dir non dir zone 4 Z1 zone 4 0 01 3000 00 ohm 0 01 56 57 Positive sequence reach zone 4 Z1 angle zone 4 15 0 90 0 deg 0 1 45 0 Positive sequence line angle zone 4 Z1 rever...

Page 991: ...zone 5 0 00 3000 00 ohm 0 01 40 00 ositive sequence resistive reach zone 5 X1 zone 5 0 00 3000 00 ohm 0 01 40 00 Positive sequence reactive reach zone 5 X1 reverse zone 5 0 00 3000 00 ohm 0 01 40 00 Pos seq reactive reach in rev dir non dir zone 5 Z1 zone 5 0 01 3000 00 ohm 0 01 56 57 Positive sequence reach zone 5 Z1 angle zone 5 15 0 90 0 deg 0 1 45 0 Positive sequence line angle zone 5 Z1 rever...

Page 992: ...or res curr stabilization EF detection func tion Stab slope 2 GFC 0 00 1 00 0 01 1 00 Slope 2 for res cur rent stabilization EF detection func tion A Ph Stab value GFC 1 00 10 00 xIn 0 01 2 00 Phase current start value for slope 2 EF detection func tion Dir mode EF GFC 1 Non directional 2 Forward 3 Reverse 1 Non directional Directional mode earth fault direc tional function Pol quantity GFC 1 Zro ...

Page 993: ...1 40 00 Parallel line zero se quence mutual re sistance zone 3 Mutual X0 zone 3 0 00 3000 00 ohm 0 01 40 00 Parallel line zero se quence mutual re actance zone 3 Tilt angle zone 4 45 45 deg 1 0 Tilt angle posi tive value increases zone area zone 4 Par line Comp zone 4 0 False 1 True 0 False Enable parallel line compensation for PE loops zone 4 Mutual R0 zone 4 0 00 3000 00 ohm 0 01 40 00 Parallel ...

Page 994: ...A 9 Acyc C A B 10 Acyc C B A 1 No filter Phase preference mode for high im pedance earthed network Impedance mode Zn 1 Rectangular 2 Polar 1 Rectangular Impedance charac teristic underimpe dance PSL Impedance Chr Gnd Zn 1 Quadrilateral 2 Mho circular 3 Mho Dir line 4 Offset Dir line 5 Bullet combi 1 Quadrilateral Impedance charac teristic for PE loops zones Impedance Chr PP Zn 1 Quadrilateral 2 Mh...

Page 995: ... No fault 1 AG Fault 2 BG Fault 3 CG Fault Start signals for phases A B and C GFC RELEASE_PE Enum 5 No fault 1 AG Fault 2 BG Fault 3 CG Fault 4 AB Fault 5 BC Fault 6 CA Fault 7 ABC Fault Release signals for PE loops GFC RELEASE_PP Enum 5 BC Fault 6 CA Fault 7 ABC Fault 4 AB Fault 5 No fault Release signals for PP 3P loops GFC EARTH_FLT BOOLEAN 0 False 1 True Indication of a single phase earth faul...

Page 996: ... 00 3000 00 ohm PP 3P loop resistance zone 1 FLTLOOP_XPP FLOAT32 3000 00 3000 00 ohm PP 3P loop reactance zone 1 FLTPH_X FLOAT32 3000 00 3000 00 ohm Phase to earth reac tance in phase domain zone 1 VMEM_USED BOOLEAN 0 False 1 True Voltage memory in use status TLT_ANG_CONFLICT INT32 0 1023 Tilt angle conflict DSTPDIS Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status Time Timestamp Time Release...

Page 997: ...ond PE loop resist ance zone 1 Flt loop 2nd Rea Zn1 FLOAT32 3000 00 3000 00 ohm Second PE loop reac tance zone 1 Flt PP loop Ris Zn1 FLOAT32 3000 00 3000 00 ohm PP loop resistance zone 1 Flt PP loop Rea Zn1 FLOAT32 3000 00 3000 00 ohm PP loop reactance zone 1 Phase reactance Zn1 FLOAT32 3000 00 3000 00 ohm Phase to earth reac tance in phase domain zone 1 Fault load Dir Zn2 Enum 0 unknown 1 forward...

Page 998: ...th reac tance in phase domain zone 3 Fault load Dir Zn4 Enum 0 unknown 1 forward 2 backward 3 both Direction of fault or load zone 4 Dir resistance Zn4 FLOAT32 3000 00 3000 00 ohm Direction resistance zone 4 Dir reactance Zn4 FLOAT32 3000 00 3000 00 ohm Direction reactance zone 4 Flt loop 1st Ris Zn4 FLOAT32 3000 00 3000 00 ohm First PE loop resist ance zone 4 Flt loop 1st Rea Zn4 FLOAT32 3000 00 ...

Page 999: ...ault 3 CAG Fault 2 BCG Fault 1 ABG Fault 1 AG Fault 2 BG Fault 3 CG Fault 4 AB Fault 5 BC Fault 6 CA Fault 7 ABC Fault Release signals for PE loops GFC Release PP loop Enum 5 No fault 4 ABCG Fault 3 CAG Fault 2 BCG Fault 1 ABG Fault 1 AG Fault 2 BG Fault 3 CG Fault 4 AB Fault 5 BC Fault 6 CA Fault 7 ABC Fault Release signals for PP 3P loops GFC Cross country fault BOOLEAN 0 False 1 True Indication...

Page 1000: ...3000 00 ohm Direction reactance zone 2 Flt loop 1st Ris Zn2 FLOAT32 3000 00 3000 00 ohm First PE loop resist ance zone 2 Flt loop 1st Rea Zn2 FLOAT32 3000 00 3000 00 ohm First PE loop reactance zone 2 Flt loop 2nd Ris Zn2 FLOAT32 3000 00 3000 00 ohm Second PE loop resist ance zone 2 Flt loop 2nd Rea Zn2 FLOAT32 3000 00 3000 00 ohm Second PE loop reac tance zone 2 Flt PP loop Ris Zn2 FLOAT32 3000 0...

Page 1001: ...nce zone 4 Flt PP loop Rea Zn4 FLOAT32 3000 00 3000 00 ohm PP loop reactance zone 4 Phase reactance Zn4 FLOAT32 3000 00 3000 00 ohm Phase to earth reac tance in phase domain zone 4 Fault load Dir Zn5 Enum 0 unknown 1 forward 2 backward 3 both Direction of fault or load zone 5 Dir resistance Zn5 FLOAT32 3000 00 3000 00 ohm Direction resistance zone 5 Dir reactance Zn5 FLOAT32 3000 00 3000 00 ohm Di...

Page 1002: ...ones INT32 0 31 Operate signal of all zones Fault load Dir Zn1 Enum 0 unknown 1 forward 2 backward 3 both Direction of fault or load zone 1 Dir resistance Zn1 FLOAT32 3000 00 3000 00 ohm Direction resistance zone 1 Dir reactance Zn1 FLOAT32 3000 00 3000 00 ohm Direction reactance zone 1 Flt loop 1st Ris Zn1 FLOAT32 3000 00 3000 00 ohm First PE loop resist ance zone 1 Flt loop 1st Rea Zn1 FLOAT32 3...

Page 1003: ...rd 2 backward 3 both Direction of fault or load zone 3 Dir resistance Zn3 FLOAT32 3000 00 3000 00 ohm Direction resistance zone 3 Dir reactance Zn3 FLOAT32 3000 00 3000 00 ohm Direction reactance zone 3 Flt loop 1st Ris Zn3 FLOAT32 3000 00 3000 00 ohm First PE loop resist ance zone 3 Flt loop 1st Rea Zn3 FLOAT32 3000 00 3000 00 ohm First PE loop reactance zone 3 Flt loop 2nd Ris Zn3 FLOAT32 3000 0...

Page 1004: ... Zn5 FLOAT32 3000 00 3000 00 ohm First PE loop resist ance zone 5 Flt loop 1st Rea Zn5 FLOAT32 3000 00 3000 00 ohm First PE loop reactance zone 5 Flt loop 2nd Ris Zn5 FLOAT32 3000 00 3000 00 ohm Second PE loop resist ance zone 5 Flt loop 2nd Rea Zn5 FLOAT32 3000 00 3000 00 ohm Second PE loop reac tance zone 5 Flt PP loop Ris Zn5 FLOAT32 3000 00 3000 00 ohm PP loop resistance zone 5 Flt PP loop Rea...

Page 1005: ...ge extended to 180 180 Setting Min phase angle zone range extended to 90 150 Setting Max phase angle zone range exten ded to 0 60 4 7 2 Out of step OOSRPSB ANSI 78PS 4 7 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Out of step protection with double blinders OOSRPSB OOS 78PS 4 7 2 2 Function block Figure 558 Function block ...

Page 1006: ...nputs Input Description I3P Three phase currents U3P Three phase voltages See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 936 Special conditions Condition Description U3P connected to real measurements The function can work with any two voltage channels connected but it is rec...

Page 1007: ...verse reach and Impedance angle settings Forward reach defines the impedance from the origin to the edge of circle on the top side Reverse reach defines the impedance from the origin to the edge of the circle on the bottom side The diameter of the mho characteristics is the sum of Forward reach and Reverse reach settings Two sets of blinders are defined by Inner blinder R and Outer blinder R inter...

Page 1008: ...eristic but inside the area that is bound with the magnitude of the minimum positive sequence current defined by setting Min Ps Seq Figure 561 shows the three zones Settings that determine the shape of the zones should be coordinated with the settings for any distance protection functions The zones and their respective slip counters are applicable only for Way out operations when the Oos operation...

Page 1009: ... The available options are Way in Way out and Adaptive If the Way in option is selected the function triggers the delay timer after detecting an OSB condition When the set Operate delay time has elapsed the OPERATE output is activated When using the Way in option the zone related settings and zone slip counters are not applicable If the Way out option is selected after detecting an OSB condition t...

Page 1010: ...m when the relay issues a trip command to the time when the breaker receives the command The function uses the Breaker open time setting to determine the trip delay time if it is not set to 0 If the Breaker open time is set to 0 the function does not dynamically calculate a trip delay but uses the fixed Operate delay time before activating the OPERATE output The slip frequency is calculated using ...

Page 1011: ...TE output can be set by Operate dropout time setting If the polarity of the voltage signal is opposite to the normal polarity the correction can be done by setting Voltage reversal to Yes which rotates the impedance vector by 180 degrees The DISABLE input can be used to coordinate the correct operation during the start up situation The function is blocked by activating the DISABLE signal Once the ...

Page 1012: ...dance using two impedance measurement elements known as blinders together with a timing device If the measured impedance stays between the blinders for a predetermined time the function declares a power swing condition and asserts an output that can be used to block the distance protection However if the impedance passes the inner blinder and exits on the other side of the mho characteristics that...

Page 1013: ...ettings Table 939 OOSRPSB Group settings Basic Parameter Values Range Unit Step Default Description Oos operate mode 1 Way in 2 Way out 3 Adaptive 2 Way out Operate mode for tripping when out of step condition is detected Forward reach 0 00 6000 00 ohm 0 01 1000 00 Forward reach of mho circle Reverse reach 0 00 6000 00 ohm 0 01 100 00 Reverse reach of mho circle Inner blinder R 1 00 6000 00 ohm 0 ...

Page 1014: ... 0 No Enable zone 2 fea ture Zone 3 enable 1 Yes 0 No 0 No Enable zone 3 fea ture Table 941 OOSRPSB Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 942 OOSRPSB Non group settings Advanced Parameter Values Range Unit Step Default Description Min Ps Seq current 0 01 10 00 xIn 0 01 0 10 Minimum positive sequence current fo...

Page 1015: ... Technical data Table 944 OOSRPSB Technical data Characteristic Value Impedance reach Depending on the frequency of the meas ured current and voltage fn 2 Hz 3 0 of the reach value or 0 2 of Un 3 I n Reset time 1 0 of the set value or 40 ms Operate time accuracy 1 0 of the set value or 20 ms Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 4 7 3 Three phase underexcitation protection U...

Page 1016: ...tion itself 4 7 3 4 Analog channel configuration UEXPDIS has two analog group inputs which all must be properly configured Table 945 Analog inputs Input Description I3P Three phase currents U3P Three phase voltages See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 946 Special co...

Page 1017: ... U_B_BC U_C_CA I1 U1 t Timer Figure 564 Functional module diagram Impedance calculation This module calculates the apparent impedance based on the selected voltages and currents The Measurement mode and Phase Sel for Z Clc settings determine which voltages and currents are to be used If the Measurement mode is set to 1Phase earth or 1Phase phase the Phase Sel for Z Clc setting is needed for determ...

Page 1018: ...is not reliable and the impedance calculation is disabled U N is the rated phase to phase voltage The calculated impedance magnitudes and angles are available in the Monitored data view The impedance angles are provided between 180 180 degrees The calculated apparent impedance is converted to pu impedance as the operating characteristics are defined with the pu settings Impedance reach check The o...

Page 1019: ... with the help of settings Restraint enable Rst offset X and Rst offset X angle as shown in the Figure Figure 566 X Reactance R Resistance X R Underexcitation protection Restrain area Rst offset X Rst offset X angle Directional restraint Figure 566 Settings Restraint enable Rst offset X and Rst offset X angle 1MRS759142 F Protection functions REX640 Technical Manual 1019 ...

Page 1020: ...lay time the operating timer resets and the START output is deactivated The Timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operating time DT The value isavailable in the Monitored data view Blocking logic There are three operation modes in the blocking functionality The operation modes are controlled by the BLOCK input an...

Page 1021: ...citation H Xe 0 2 Xs 0 0 37o 18o Where AB Field current limit BC Stator current limit CD End region heating limit of stator Due to leakage flux BH Possible active power limit due to turbine output power limitation EF Steady state limit without AVR Figure 567 Capability curve of a synchronous generator UEXPDIS protects the synchronous machines against an unstable operation due to loss of excitation...

Page 1022: ...strain area of the underexcitation protection along withRst offset X angle If the sign of the Rst offset X setting is positive the restraint line passes through a point on X axis which is above the R axis and if it is negative it passes through a point on X axis which is below the R axis Rst offset X angle Angle between the R axis or Rst offset X line and the directional restraint line If the sign...

Page 1023: ...in the network 4 7 3 7 Signals UEXPDIS Input signals Table 949 UEXPDIS Input signals Name Type Default Description I3P SIGNAL Three phase currents U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode EXT_LOS_DET BOOLEAN 0 False External signal for excitation loss detec tion UEXPDIS Output signals Table 950 UEXPDIS Output signals Name Type Description...

Page 1024: ... angle 180 0 180 0 deg 0 1 13 0 Angle between R axis and directional line Table 953 UEXPDIS Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On External Los Det Ena 0 Disable 1 Enable 1 Enable Enable external ex citation loss detec tion Voltage reversal 0 No 1 Yes 0 No Rotate voltage sig nals by 180 degrees Impedance Meas mode 1 ...

Page 1025: ...im pedance amplitude Z_ANGLE_BC FLOAT32 180 00 180 00 deg Phase to phase B C im pedance phase angle Z_AMPL_CA FLOAT32 0 00 200 00 xZn Phase to phase C A im pedance amplitude Z_ANGLE_CA FLOAT32 180 00 180 00 deg Phase to phase C A im pedance phase angle Z1_AMPL FLOAT32 0 00 200 00 xZn Positive sequence im pedance amplitude Z1_ANGLE FLOAT32 180 00 180 00 deg Positive sequence im pedance phase angle ...

Page 1026: ...ce number Three phase underimpedance pro tection UZPDIS Z G 21G 4 7 4 2 Function block Figure 569 Function block 4 7 4 3 Functionality The three phase underimpedance protection UZPDIS is generally applied as a backup protection for generators and transformers against short circuit faults The protection is based on the origin centric circular characteristics on the impedance plane The function calc...

Page 1027: ...ance Meas mode is set to 1Phase to phase The function requires that at least two the third voltage will be derived or all three voltage channels are connected if Impedance Meas mode is set to 3Phase to phase Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the co...

Page 1028: ... voltages AB BC and CA and currents should be used for calculating the impedance Table 960 Voltages and currents used in impedance calculation Impedance Meas mode Phase Sel for Z Clc Voltages and currents used in impedance calculation 1 1Phase phase AB ZAB U AB I A I B _ _ _ 1Phase phase BC ZBC U BC I B I C _ _ _ 1Phase phase CA ZCA U CA I C I A _ _ _ 3Phase phase N A ZAB U AB I A I B _ _ _ ZBC U ...

Page 1029: ...impedance plane The origin centric circular characteristic is defined using the Polar reach setting If the calculated impedance value enters the circle in the impedance plane the module sends an enabling signal to start the Timer Figure 571 Origin centric circular operating characteristics Separate zones with an offset mho characteristic can be designed using multiple instances of the UZPDIS funct...

Page 1030: ...vailable when Impedance Meas mode is set to 3Phase phase and the function considers the lowest impedance value for starting and operating Timer Once activated the Timer activates START output The time characteristic is according to DT When the duration of the underimpedance condition exceeds the set definite Operate delay time the OPERATE output is activated If the impedance locus moves out of cir...

Page 1031: ... against short circuit faults at the generator terminals or on the high voltage side of a step up transformer This function can be used either instead of the definite time voltage dependent overcurrent protection or to obtain a limited protection zone and the optimum operating time instead of the non directional overcurrent protection Comparison between overcurrent and underimpedance protection Ph...

Page 1032: ... square root of 2 The phase voltage in a three phase short circuit when a fault occurs at time 0 s is shown in Figure 574 The voltage drop caused by a three phase fault provides more time for determining the fault by means of an underimpedance protection Protection functions 1MRS759142 F 1032 REX640 Technical Manual ...

Page 1033: ...edance trajectory during a short circuit the fault impedance remains inside the impedance circle for a longer time in which case the underimpedance protection provides longer tripping delay times to maintain the time selectivity 1MRS759142 F Protection functions REX640 Technical Manual 1033 ...

Page 1034: ...tailed calculations are necessary for a good coverage The Polar reach setting is set to a value equal to 150 percent of the transformer short circuit impedance The setting also provides a backup protection for the busbar and feeder faults on the HV side Underimpedance protection for generators The underimpedance protection is set to protect the zone between the generator windings and the generator...

Page 1035: ...locking guidelines The operation of the underimpedance protection must be restrained if the voltage in one or more phases suddenly drops close to zero without any significant change in the current observed at the same time This situation is considered as a fuse failure or a miniature circuit breaker operation in the voltage transformer secondary circuit The voltage drop could cause an unwanted ope...

Page 1036: ... 10 200 Operate delay time Table 964 UZPDIS Group settings Advanced Parameter Values Range Unit Step Default Description Offset enable 0 Disable 1 Enable false Enable offset mho characteristic Offset 1000 1000 Zn 1 10 Offset of top of the impedance cir cle from the R axis Displacement 1000 1000 Zn 1 0 Displacement of impedance circle centre from the X axis Table 965 UZPDIS Non group settings Basic...

Page 1037: ... pedance amplitude Z_AMPL_BC FLOAT32 0 00 200 00 xZn Phase to phase B C im pedance amplitude Z_AMPL_CA FLOAT32 0 00 200 00 xZn Phase to phase C A im pedance amplitude UZPDIS Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 7 4 10 Technical data Table 968 UZPDIS Technical data Characteristic Value Operation accuracy Depending on the frequency of the meas ured current and voltage fn 2 Hz 3 0...

Page 1038: ...ionality Directional negative sequence impedance protection function DNZPDIS is used to detect the unsymmetrical fault such as the phase to phase fault phase ground fault and double phase to ground fault on power system network Operating principle is based on negative sequence impedance Function compares the negative sequence impedance value against given setting values Directional operation is ba...

Page 1039: ...TE Blocking logic START Impedance calculation Low Level blocking Fault direction detector FAULT_DIR DIRECTION U3P I3P U2 I2 I1 t Timer Figure 578 Functional module diagram Low level blocking This module receives positive sequence current I1 and negative sequence current I2 Both are calculated from fundamental frequency three phase currents Low level blocking is used to block the Impedance calculat...

Page 1040: ...only forward direction can be achieved by setting the Direction mode to Forward Thus forward fault is detected if the value of Z2 is higher than the Ng Seq impedance Fw setting Respectively operation to only reverse direction can be activated by setting Direction mode is set to Reverse Reverse fault is detected if the value of Z2 is below the setting Ng Seq impedance Rv setting In case Direction m...

Page 1041: ... of the start situation and the set operation time The value is available in the monitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting in Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication i...

Page 1042: ...d false tripping with systems having un transposed lines where some default negative sequence current will be present during normal operation Application example Relay setting calculation for the DNZPDIS function is shown with below application example of parallel lines with two end sources of power system network G G Line 1 Line 2 DNZPDIS CB1 CB3 CB4 CB2 Forward fault Reverse fault 3 Figure 580 P...

Page 1043: ...example shown in Figure 580 the relay is located at the sending end of the line1 and the output is captured for forward and reverse direction fault The phase A to ground fault is applied on the line1 in the forward direction the Z2 value is positive as well as exceeds the Ng seq impedance Fw setting threshold hence the START output issued FAULT_DIR indicates the fault in the forward direction and ...

Page 1044: ...ents U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode DNZPDIS Output signals Table 974 DNZPDIS Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start FAULT_DIR Enum Detected fault direction DIRECTION Enum Direction information 4 7 5 8 Settings Protection functions 1MRS759142 F 1044 REX640 Technical Manual ...

Page 1045: ...current Rv 0 05 1 00 xIn 0 01 0 05 Minimum reverse negative sequence current threshold Characteristic an gle 1 90 deg 1 67 Characteristic an gle Table 976 DNZPDIS Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 977 DNZPDIS Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time ...

Page 1046: ...ality The power swing detection function DSTRPSB detects power swing condition and can be used for blocking the distance protection function The power swing detection function comprises an inner and an outer impedance characteristic The supported zone characteristic shapes for inner and outer characteristic are quadrilateral and mho circular The power swing detection function is supervised by a lo...

Page 1047: ...all three voltage channels 4 7 6 5 Operation principle The Operation setting is used to enable or disable the function When selected On the function is enabled and respectively Off means function is disabled The operation of DSTRPSB can be described by using a module diagram see figure below All the modules in the diagram are explained in the next sections BLOCK PSB Power swing detection Impedance...

Page 1048: ...nts Negative sequence current level can be monitored if Ng Seq current Spvn is set to Enable When the negative sequence current is above the Max Ng Seq current setting longer than the time delay defined by the setting Neg Seq current time the Power swing detection module is disabled The module is disabled until negative sequence current drops below the setting value The Max Ng Seq current setting ...

Page 1049: ...s defined by the line reach independently with the settings Inner R1 Inner X1 Inner X1 reverse The resistive reach of inner polygon is defined at the minimum resistive reach with settings Inner Min Ris Rch The reach of outer polygon in the reactive direction is defined by the line reach independently with the settings Outer R1 Outer X1 Outer X1 reverse The resistive reach of outer polygon is defin...

Page 1050: ...nd impedance calculation 4 7 6 6 Application Describe different application possibilities of the function The application information answers one or more of the following questions The problem of the application The purpose of the function Solution for the problem in general level Where can the function be used When can the function be used The application information shall NOT describe what the u...

Page 1051: ...mple of power swing detection In the above figure the power swing detection characteristics and three typical positive sequence impedance trajectories are plotted For trajectory A the impedance moves into the power swing detection zone and leaves slowly indicating the occurrence of a swing that quickly stabilizes For trajectory C impedance rapidly moves into and remains in the inner characteristic...

Page 1052: ...als Name Type Default Description I3P SIGNAL Three phase currents U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode DSTRPSB Output signals Table 983 DSTRPSB Output signals Name Type Description PSB BOOLEAN Power swing detected SWING_ST BOOLEAN Impedance between inner and outer characteristic 4 7 6 8 Settings Protection functions 1MRS759142 F 1052 ...

Page 1053: ... swing detec tion timer for im pedance stays be tween the inner characteristic and outer characteristic Load discrimina tion 0 False 1 True 0 False Enable load dis crimination Inner Fw Ld Ris Rch 0 01 6000 00 ohm 0 01 15 00 Resistive forward reach of inner char acteristic for load discrimination Inner Rv Ld Ris Rch 0 01 6000 00 ohm 0 01 15 00 Resistive reverse reach of inner char acteristic for lo...

Page 1054: ... Slow swing time 80 60000 ms 10 2000 Time for slow swing supervision blocking the func tion Pulse time 20 60000 ms 10 500 Time for holding output PSB 4 7 6 9 Monitored data DSTRPSB Monitored data Table 987 DSTRPSB Monitored data Name Type Values Range Unit Description Z1_AMPL FLOAT32 0 00 99999 00 ohm Positive sequence im pedance amplitude Z1_ANGLE FLOAT32 180 00 180 00 deg Positive sequence im pe...

Page 1055: ...ty The underpower protection function DUPPDPR is used for protecting generators and prime movers against the effects of very low power outputs or reverse power condition The function operates when the measured active power falls below the set value The operating characteristics are according to definite time DT This function contains a blocking functionality It is possible to block the function ou...

Page 1056: ...l configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 4 8 1 5 Operation principle The function can be enabled and disabled...

Page 1057: ...n of power insensitive to the possible asymmetry in currents or voltages and corresponds to the real load of the prime mover of the generator S s Table 991 Power calculation Measurement mode setting Power calculation PhsA PhsB PhsC S U I U I U I a a b b c c P S Re Arone S U I U I ab a bc c P S Re Pos Seq S U I 3 1 1 P S Re PhsAB S U I I ab a b 3 P S Re PhsBC S U I I bc b c 3 P S Re PhsCA S U I I c...

Page 1058: ...ed power is considered to be in the forward direction if the active power is positive else it is considered to be in the reverse direction A typical error is for example that the VT or CT poles are wrongly connected This is seen as a power flow opposite to that of the intended direction The Pol Reversal setting can be used to correct the situation By setting the value to True the measured apparent...

Page 1059: ...data The DISABLE input can be used to coordinate the correct operation during the generator start up situation By activating the DISABLE signal both the START and OPERATE outputs are blocked Once the DISABLE signal is deactivated the Timer remains blocked for an additional time duration as set through the setting Disable time Blocking logic There are three operation modes in the blocking functiona...

Page 1060: ...he rest of the system to feed their internal losses Hence it is desirable to disconnect the generator in such situations In case of the parallel connected generators for example the load of one generator may be so low that it is better to disconnect it and let the remaining generators feed the network Where a low value of power setting is required for example less than 2 the correction parameters ...

Page 1061: ...Default Description Measurement mode 1 PhsA PhsB PhsC 2 Arone 3 Pos Seq 4 PhsAB 5 PhsBC 6 PhsCA 7 PhsA 8 PhsB 9 PhsC 3 Pos Seq Selection of power calculation method Reset delay time 0 60000 ms 10 20 Reset delay time Pol reversal 0 False 1 True 0 False Reverse the defini tion of the power direction Disable time 0 60000 ms 1000 0 Additional wait time after CB clos ing 4 8 1 9 DUPPDPR Monitored data ...

Page 1062: ...Typically 30 ms Reset ratio Typically 1 04 Operate time accuracy 1 0 of the set value of 20 ms Suppression of harmonics 50 dB at f n fn where n 2 3 4 5 4 8 2 Reverse power directional overpower protection DOPPDPR ANSI 32R 32O 4 8 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Reverse power directional over power protection DO...

Page 1063: ...haracteristics are according to definite time DT This function contains a blocking functionality It is possible to block the function outputs timer or the function itself 4 8 2 4 Analog channel configuration DOPPDPR has two analog group inputs which must be properly configured Table 999 Analog inputs Input Description I3P Three phase currents U3P Three phase voltages See the preprocessing function...

Page 1064: ...RATE START Directional calculation U3P I3P Power calculation Level detector t Timer U_AB U_BC U_CA I_A I_B I_C U1 I1 Figure 593 Functional module diagram Power calculation This module calculates the apparent power based on the selected voltages and currents The Measurement mode setting determines which voltages and currents are used It is also possible to use positive sequence components for calcu...

Page 1065: ...or angle PF_ANGL are available in the Monitored data view Level detector The Level detector compares the magnitude of the measured apparent power to the set Start value If the measured value exceeds the set Start value the Level detector sends an enabling signal to the Timer module Directional calculation The Directional calculation module monitors the direction of the apparent power When the appa...

Page 1066: ...T or CT poles are wrongly connected This is seen as a power flow opposite to that of the intended direction The Pol Reversal setting can be used to correct the situation By setting the value to True the measured apparent power is turned 180 degrees Non operating area Operating area P Q Start value Figure 594 Operating characteristics with the Start Value setting the Power angle setting being 0 and...

Page 1067: ...Monitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the protection relay s program The influence of the BL...

Page 1068: ... axially and touches stationary parts They are not always strong enough to withstand the associated stresses A hydroturbine that rotates in water with the closed wicket gates draws about 10 of the rated power from the rest of the power system if the intake is blocked due to ice snow branches or leaves A complete blockage of the intake may cause cavitations If there is only air in the hydroturbine ...

Page 1069: ...cteristics a and forward reactive overpower characteristics b P Q Non operating area Operating area P Q Operating area Non operating area a b Figure 597 Reverse active overpower characteristics a and reverse reactive overpower characteristics b 4 8 2 7 Signals 1MRS759142 F Protection functions REX640 Technical Manual 1069 ...

Page 1070: ...er Values Range Unit Step Default Description Start value 0 01 2 00 xSn 0 01 1 00 Start value Operate delay time 40 300000 ms 10 40 Operate delay time Directional mode 2 Forward 3 Reverse 2 Forward Directional mode Power angle 90 90 deg 1 0 Adjustable angle for power Table 1005 DOPPDPR Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation...

Page 1071: ... 180 00 deg Power factor angle DOPPDPR Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 8 2 10 Technical data Table 1008 DOPPDPR Technical data Characteristic Value Operation accuracy 1 Depending on the frequency of the measured current and voltage f fn 2 Hz Power measurement accuracy 3 of the set value or 0 002 Sn Phase angle 2 Start time 2 3 Typically 45 ms Reset time Typically 30 ms Res...

Page 1072: ...ltages and current at the grid connection point The generating facility is disconnected from the network with a specific time delay if all phase voltages decrease and remain at or below the specified limit and if reactive power is simultaneously consumed that is under excitation operation DQPTUV contains a blocking functionality to block function outputs timer or the function itself 4 8 3 4 Analog...

Page 1073: ...ed using a module diagram All the modules in the diagram are explained in the next sections Reactive power monitoring Under voltage detection BLOCK OPERATE START U3P I3P I1 U1 U_AB U_BC U_CA Timer t Blocking logic Figure 599 Functional module diagram Under voltage detection Under voltage detection compares the fundamental frequency component of all three phase to phase voltages with the set Voltag...

Page 1074: ...rection can be reversed by setting Pol reversal to True Timer Once activated by both Under voltage detection and Reactive power monitoring module the Timer activates the START output The Timer characteristic is according to DT When the operation timer has reached the value set by Operate delay time the OPERATE output is activated If the fault disappears before the module operates the Timer is rese...

Page 1075: ...e revised their requirements and therefore require that the distributed PGUs have to make a contribution to network support In case of network faults the distributed power generator should not be immediately disconnected from the network Instead as a matter of principle generating plants connected to the medium voltage network must be capable of participating in steady state voltage control and dy...

Page 1076: ...nf ANSI IEC 25 27RT 32Q 27 32R 32O 47O 59 47U 27 50L 50NL 60 78V 81 SYNC U RT Q 3U P Q U2 3U U1 3U ARC FUSEF VS f f df dt A Figure 601 Application example of wind power plant as distributed power generation coupled into the utility network 4 8 3 7 Signals Protection functions 1MRS759142 F 1076 REX640 Technical Manual ...

Page 1077: ...der voltage detec tion Operate delay time 100 300000 ms 10 500 Operate delay time Table 1014 DQPTUV Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation On Off Table 1015 DQPTUV Non group settings Advanced Parameter Values Range Unit Step Default Description Min reactive power 0 01 0 50 xSn 0 01 0 05 Minimum reactive power needed for fun...

Page 1078: ...of the set value or 0 002 Un Start time 1 2 Typically 46 ms Reset time 50 ms Reset ratio Typically 0 96 Operate time accuracy 1 0 of the set value or 20 ms Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 4 8 4 Underpower factor protection MPUPF ANSI 55U 4 8 4 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Underpowe...

Page 1079: ...ee phase currents U3P Three phase voltages See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 1019 Special conditions Condition Description U3P connected to real meas urements The function requires that any two voltage channels are con nected Improper analog channel configuration...

Page 1080: ...tion This module calculates three phase power factor using phase currents and voltages The three phase power is calculated from the fundamental frequency components DFT of the phase to earth voltages and phase to earth currents S U I U I U I A A B B C C Figure 604 Equation P S Re Figure 605 Equation PF P S Figure 606 Equation Figure 607 shows the resulting sign of the power factor This should be c...

Page 1081: ...e startup situation By activating the DISABLE signal the power factor calculation is blocked Once the DISABLE signal is deactivated the function remains blocked for additional time duration as set through the setting Disable time Level detector 1 The Level detector 1 compares the calculated power factor to the set Start value If the power factor value goes below the set Start value in the directio...

Page 1082: ...ozen to the prevailing value but the OPERATE output is not deactivated when blocking is activated In the Block all mode the whole function is blocked and the timers are reset In the Block OPERATE output mode the function operates normally but the OPERATE output is not activated 4 8 4 6 Application The MPUPF function can be used to detect loss of excitation or for power factor correction Synchronou...

Page 1083: ...n is well suited to protect against back spinning In this case the start reset value will only come into play once the system provides power in the opposite quadrant of the start value for example lagging PF turns to leading PF 4 8 4 7 Signals MPUPF Input signals Table 1020 MPUPF Input signals Name Type Default Description I3P SIGNAL Three phase currents U3P SIGNAL Three phase voltages BLOCK BOOLE...

Page 1084: ...on group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Min operate current 0 05 0 65 xIn 0 01 0 10 Minimum operating current Min operate volt age 0 05 0 50 xUn 0 01 0 10 Minimum operating voltage Disable time 0 60000 ms 1 5000 Additional wait time after CB clos ing Voltage reversal 0 No 1 Yes 0 No Rotates the PF by 180 degrees Table ...

Page 1085: ...rc protection ARCSARC ARC AFD 4 9 2 Function block Figure 608 Function block 4 9 3 Functionality The arc protection function ARCSARC detects arc situations in air insulated metal clad switchgears caused by for example human errors during maintenance or insulation breakdown during operation The function detects light from an arc either locally or via a remote light signal The function also monitors...

Page 1086: ...otection relay once the mismatch is corrected 4 9 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The operation of ARCSARC can be described by using a module diagram All the modules in the diagram are explained in the next sections OPERATE Level detector 1 I3P BLOCK Level detector 2 IRES REM_FLT_ARC ARC_FLT...

Page 1087: ...y mode or on remotely controlled information in BI controlled mode When the BI controlled mode is in use and the OPR_MODE input is activated the operation of the function is based on light information only When the OPR_MODE input is deactivated the operation of the function is based on both light and current information When the required criteria are met Fixed delay 1 timer is activated Fixed dela...

Page 1088: ...pared to an automatically adjusted reference level Each light sensor input has its own reference level When the light exceeds the reference level of one of the inputs the light is detected locally When the light has been detected locally or remotely and depending on the operation mode if one or several phase currents exceed the set Phase start value limit or the earth fault current the set Ground ...

Page 1089: ...M1 SPO1 SPO3 3I Q1 Q2 Q3 Q4 Q5 Q6 M1 Figure 610 Arc protection with one protection relay 1MRS759142 F Protection functions REX640 Technical Manual 1089 ...

Page 1090: ...ignal the protection relay protecting the incoming feeder trips the circuit breaker of the incoming feeder and generates an external trip signal to all protection relays protecting the outgoing feeders which in turn results in tripping of all circuit breakers of the outgoing feeders For maximum safety the protection relays can be configured to trip all the circuit breakers regardless of where the ...

Page 1091: ...I Io 3I Io Ethernet switch Binary horisontal GOOSE connection SPO1 SPO2 M1 S1 S2 S3 S4 Figure 612 Arc protection with several protection relays and high speed outputs and GOOSE 4 9 7 Signals 1MRS759142 F Protection functions REX640 Technical Manual 1091 ...

Page 1092: ...ight sig nal output ALARM BOOLEAN Self supervision alarm 4 9 8 ARCSARC Settings Table 1031 ARCSARC Group settings Basic Parameter Values Range Unit Step Default Description Phase start value 0 50 40 00 xIn 0 01 2 50 Operating phase current Ground start value 0 05 8 00 xIn 0 01 0 20 Operating residual current Operation mode 1 Light current 2 Light only 3 BI controlled 1 Light current Operation mode...

Page 1093: ... ms 2 5 ms 3 13 ms 2 6 ms 3 Reset time Typically 50 ms Reset ratio Typically 0 96 4 10 Motor start up supervision STTPMSU ANSI 49 66 48 50TDLR 4 10 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Motor start up supervision STTPMSU Is2t n 49 66 48 50TDL R 1 Phase start value 1 0 In current before fault 2 0 set Phase start value f...

Page 1094: ...a predefined operating time STTPMSU also protects the motor from an excessive number of start ups Upon exceeding the specified number of start ups within certain duration STTPMSU blocks further starts The restart of the motor is also inhibited after each start and continues to be inhibited for a set duration When the lock of start of motor is enabled STTPMSU gives the time remaining until the rest...

Page 1095: ...ation mode setting When the Operation mode setting is operated in the IIt mode the function calculates the value of the thermal stress of the motor during the start up condition In this mode the start up condition is detected by monitoring the TRMS currents The Operation mode setting in the IIt CB mode enables the function to calculate the value of the thermal stress when a start up is monitored i...

Page 1096: ... The beginning of the motor start up is recognized when CB is closed that is when the CB_CLOSED input is activated and at least one phase current value exceeds the Motor standstill A setting These two events do not take place at the same instant that is the CB main contact is closed first in which case the phase current value rises above 0 1 pu and after some delay the CB auxiliary contact gives t...

Page 1097: ...ted Based on the values of the phase currents the completion of the start up period cannot be judged So in this mode of operation the value of the time delay setting can even be as high as within the range of seconds for example around 30 seconds The activation of the BLOCK input signal deactivates the MOT_START output Thermal stress calculator Because of the high current surges during the start u...

Page 1098: ... resistance insertion The start up time is dependent on the load connected to the motor Based on the motor characteristics supplied by the manufacturer this module is required if the stalling time is shorter than or too close to the starting time In such cases a speed switch must be used to indicate whether a motor is accelerating during start up or not At motor standstill the STALL_IND input is a...

Page 1099: ...e reset from the Clear menu The old Number of motor start ups occurred counter value START_CNT can be taken into use by writing the value to the Ini start up counter parameter and resetting the value via the Clear menu from WHMI or LHMI The calculated values of T_RST_ENA T_ST_CNT and START_CNT are available in the Monitored data view The activation of the BLK_LK_ST input signal deactivates the LOC...

Page 1100: ...gnetic field and the rotor during the start up time induces a high magnitude of slip current in the rotor at frequencies higher than when the motor is at full speed The skin effect is stronger at higher frequencies and all these factors increase the losses and the generated heat This is worse when the rotor is locked The starting current for slip ring motors is less than the full load current and ...

Page 1101: ...that calculates them This insures that the thermal effects on the motor for consecutive starts stay within permissible levels For example the motor manufacturer may state that three starts at the maximum are allowed within 4 hours and the start up situation time is 60 seconds By initiating three successive starts we reach the situation as illustrated As a result the value of the register adds up t...

Page 1102: ...time in hours 4 10 7 Signals 4 10 7 1 STTPMSU Input signals Table 1036 STTPMSU Input signals Name Type Default Description I3P SIGNAL Three phase currents BLOCK BOOLEAN 0 False Block of function BLK_LK_ST BOOLEAN 0 False Blocks lock out condi tion for restart of mo tor CB_CLOSED BOOLEAN 0 False Input showing the status of motor cir cuit breaker STALL_IND BOOLEAN 0 False Input signal for show ing t...

Page 1103: ...t Motor start up time 1 80 s 1 5 Motor starting time Lock rotor time 2 120 s 1 10 Permitted stalling time Str over delay time 0 60000 ms 1 100 Time delay to check for completion of motor startup peri od Table 1039 STTPMSU Group settings Advanced Parameter Values Range Unit Step Default Description Start detection A 0 1 10 0 xIn 0 1 1 5 Current value for detecting starting of motor Table 1040 STTPM...

Page 1104: ...ll A 0 01 0 20 xIn 0 01 0 12 Current limit to check for motor standstill condition 4 10 9 STTPMSU Monitored data Table 1042 STTPMSU Monitored data Name Type Values Range Unit Description START_CNT INT32 0 999999 Number of motor start ups occurred START_TIME FLOAT32 0 0 999 9 s Measured motor latest startup time in sec T_ST_CNT FLOAT32 0 0 99999 9 s Cumulated start up time in sec T_RST_ENA INT32 0 ...

Page 1105: ...PMSU Technical revision history Product connectivi ty level Technical revision Change PCL4 E Setting Motor standstill A minimum value changed from 0 05xIn to 0 01xIn 4 11 Multipurpose protection MAPGAPC ANSI MAP 4 11 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Multipurpose protection MAPGAPC MAP MAP 1 Current before 0 0 In f...

Page 1106: ...lock function outputs the definite timer or the function itself 4 11 4 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The operation of MAPGAPC can be described using a module diagram All the modules in the diagram are explained in the next sections AI_VALUE OPERATE Level detector Blocking logic BLOCK START T...

Page 1107: ...set delay time the operation timer resets and the START output is deactivated The timer calculates the start duration value START_DUR which indicates the percentage ratio of the start situation and the set operation time The value is available in the monitored data view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and...

Page 1108: ...11 6 Signals 4 11 6 1 MAPGAPC Input signals Table 1046 MAPGAPC Input signals Name Type Default Description AI_VALUE FLOAT32 0 0 Analogue input value BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode ENA_ADD BOOLEAN 0 False Enable start added 4 11 6 2 MAPGAPC Output signals Table 1047 MAPGAPC Output signals Name Type Description OPERATE BOOLEAN Operate START BOOLEAN Start 4 11 7 ...

Page 1109: ...rate time MAPGAPC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 11 9 Technical data Table 1052 MAPGAPC Technical data Characteristic Value Operation accuracy 1 0 of the set value or 20 ms 4 12 Capacitor bank protection 4 12 1 Three phase overload protection for shunt capacitor banks COLPTOC ANSI 51 37 86C 4 12 1 1 Identification Function description IEC 61850 identification IEC 60617 id...

Page 1110: ... possible to block the function outputs timers or the function itself 4 12 1 4 Analog channel configuration COLPTOC has one analog group input which must be properly configured Table 1053 Analog inputs Input Description I3P Three phase currents See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if t...

Page 1111: ...T_C which is proportional to the voltage over capacitor The I_PEAK_INT_A I_PEAK_INT_B and I_PEAK_INT_C values are available in monitored data view The frequency response of the peak integrated current calculator can be seen in Figure 624 Figure 624 Frequency response of the peak integrated current calculator Operate level detector The Operate level detector compares I_PEAK_INT_x value to Start val...

Page 1112: ...1 1 1 40 15 ANSI IEEE37 99 1 70 1 ANSI IEEE37 99 2 20 0 120 ANSI IEEE37 99 Operate time is based on maximum value of I_PEAK_INT_A I_PEAK_INT_B and I_PEAK_INT_C From maximum value calculated operate time between any two consecutive points in the standard table is based on logarithmic interpolation The operate time can be scaled using the Time multiplier setting The OPR_OVLOD output is activated if ...

Page 1113: ...operation timer is frozen However if the integrated current exceeds 1 1 times the Start value overload setting value again the operation timer continue from the freezing point Thus the operation timer is cumulative If the integrated current exceeds 1 1 times the setting Start value overload only once and remains within the Start value overload area for 24 hours the operation timer and the output S...

Page 1114: ...alue to Alarm start value If the phase or phases in which I_PEAK_INT_x exceeds the setting matches the Num of start phases setting the Alarm level detector module activates the Timer 2 module The Num of start phases setting is a common setting for both Operate level detector and Alarm level detector Timer 2 The Timer 2 characteristics are according to Definite Time DT When the operation timer has ...

Page 1115: ...status signal is not detected the constant value TRUE has to be connected to CB_CLOSED input to enable the undercurrent detector If the circuit breaker status signal is not connected to CB_CLOSED input the OPR_UN_I output is activated even if the circuit breaker is open and undercurrent is detected Inhibit reclose When the output OPR_UN_I becomes active or when the CB_CLOSED state changes from TRU...

Page 1116: ...across the capacitor bank According to the standards a high voltage capacitor shall be able to withstand 10 overload Loading beyond that can cause damage to the capacitor bank and in turn to the system Hence COLPTOC is specially designed for the protection against overloads produced by harmonic currents and overvoltage Undercurrent protection is used to disconnect the capacitor bank from the rest ...

Page 1117: ... Settings Table 1057 COLPTOC Group settings Basic Parameter Values Range Unit Step Default Description Start value over load 0 30 1 50 xIn 0 01 1 00 Start value for over load stage Alarm start value 80 120 1 105 Alarm start value of Start value overload Start value Un Cur 0 10 0 70 xIn 0 01 0 50 Start value for un der current opera tion Time multiplier 0 05 2 00 0 01 1 00 Time multiplier for Capac...

Page 1118: ...T_DUR_OVLOD FLOAT32 0 00 100 00 Start duration for over load stage ST_DUR_UN_I FLOAT32 0 00 100 00 Start duration for under current operation I_PEAK_INT_A FLOAT32 0 00 40 00 Phase A peak value of the integrated current of the capacitor I_PEAK_INT_B FLOAT32 0 00 40 00 Phase B peak value of the integrated current of the capacitor I_PEAK_INT_C FLOAT32 0 00 40 00 Phase C peak value of the integrated c...

Page 1119: ...dI C 60N 4 12 2 2 Function block Figure 627 Function block symbol 4 12 2 3 Functionality The current unbalance protection for shunt capacitor banks function CUBPTOC is used to protect the double Y connected capacitor banks from internal faults CUBPTOC is suitable for the protection of internally fused externally fused and fuseless applications CUBPTOC has two stages of operation that is operation ...

Page 1120: ...65 Special conditions Condition Description IUNB measurement The function requires that the unbalance current measure ment is connected via the RESTCTR function block Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the prepr...

Page 1121: ...e common neutral connecting the two balanced parts of a shunt capacitor bank that is between star point 1 and star point 2 Figure 629 Double Y connected capacitor bank The phase angle of the measured fundamental frequency component of the unbalance current I_UNB is synchronized by using the phase current I_A as a reference I I UNB I A unb _ _ Equation 285 In a three phase star connected capacitor ...

Page 1122: ...rrent is recorded during further executions of the function the natural unbalance current is subtracted from the measured unbalance current IUnb to obtain the compensated unbalance current ICompUnb as shown in Figure 630 Figure 630 Natural unbalance compensation a Healthy condition when the natural unbalance is recorded b Unbalance compensation during faulty conditions The natural unbalance curren...

Page 1123: ...apsed The setting Time multiplier is used for scaling the IDMT operation and reset times The setting parameter Minimum operate time defines the minimum desired operation time for IDMT The setting is applicable only when the IDMT curves are used The Minimum operate time setting should be used with great care because the operation time is according to the IDMT curve but always at least the value of ...

Page 1124: ...h2 COUNT_BR2_B 15 45 Phase A branch1 Phase B branch2 COUNT_BR1_A COUNT_BR2_B If the capacitor bank is fuseless then the setting Fuse location should be set to External and Table 1066 can be used to determine the element failure location If the compensated unbalance current I_AMPL_COMP is greater than three times the set Alarm value it is considered to be a case of blown external fuse For the inter...

Page 1125: ... times the set Alarm value the counter is incremented by one Furthermore if I_AMPL_COMP is between 1 5 and 2 5 times the set Alarm value the counter is incremented by two and so on Normally the setting Alarm value is about 0 1 percent lower than the value of the unbalance current which is caused by one faulty element This setting value has to be chosen carefully because a slightly lower value may ...

Page 1126: ...ode the operation timer is frozen to the prevailing value In the Block all mode the whole function is blocked and the timers are reset In the Block OPERATE output mode CUBPTOC operates normally but the OPERATE output is not activated 4 12 2 6 Application CUBPTOC is designed for the protection against internal faults in double Y connected capacitor banks This unbalance protection detects an asymmet...

Page 1127: ...evel is normally set to 50 percent of the maximum permitted level The capacitor bank needs to be taken out of service to replace the faulty units If this is not done the capacitor bank is tripped when the maximum allowed unbalance current level is exceeded If two simultaneous faults occur in the same phase but in different branches there is no change in the unbalance current and CUBPTOC does not d...

Page 1128: ...The natural unbalance recording should be made only during the steady state condition and when all the capacitor bank elements are assumed to be in service 4 12 2 7 Signals CUBPTOC Input signals Table 1068 CUBPTOC Input signals Name Type Default Description IUNB SIGNAL Analog input I3P SIGNAL Three phase currents BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode CUBPTOC Output s...

Page 1129: ...me Table 1071 CUBPTOC Group settings Advanced Parameter Values Range Unit Step Default Description Fuse location 1 Internal 2 External 1 Internal Location of capaci tor fuse Element fail limit 1 100 1 3 Element failure lim it above which alarm is active Natural Comp ena ble 0 False 1 True 0 False Enable natural un balance compensa tion Table 1072 CUBPTOC Non group settings Basic Parameter Values R...

Page 1130: ...ent fail ures in branch1 phase A COUNT_BR2_A INT32 0 2147483647 Number of element fail ures in branch2 phase A COUNT_BR1_B INT32 0 2147483647 Number of element fail ures in branch1 phase B COUNT_BR2_B INT32 0 2147483647 Number of element fail ures in branch2 phase B COUNT_BR1_C INT32 0 2147483647 Number of element fail ures in branch1 phase C COUNT_BR2_C INT32 0 2147483647 Number of element fail u...

Page 1131: ...rotect the H bridge capacitor banks against internal faults HCUBPTOC is suitable for protection of internally fused externally fused and fuse less capacitor bank applications HCUBPTOC has two stages of operation the operation stage and alarm stage In the operation stage HCUBPTOC starts when the measured unbalance current exceeds the set limit The operating time characteristics can be selected to b...

Page 1132: ... 12 3 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The three phase current unbalance protection for shunt capacitor banks operates on the DFT measurement mode The operation of HCUBPTOC can be described by using a module diagram All the modules in the diagram are explained in the next sections BLOCK OPERA...

Page 1133: ...h Control HCUBPTOC The natural unbalance currents are recorded for all the phases at the same time by setting command Record unbalance to Record all phases or each natural unbalance current can be recorded separately for individual phases by setting command Record unbalance to Record phase A or Record phase B or Record phase C By selecting Record unbalance with value Record the measured three phas...

Page 1134: ...nb_A Phase A recorded natural unbalance current The phasewise compensated unbalance current amplitudes and angles I_COM_AMPL_A I_COM_ANGL_A I_COM_AMPL_B I_COM_ANGL_B I_COM_AMPL_C and I_COM_ANGL_C are available in the monitored data view The phase angles of the unbalance currents indicate the branch of a faulty element in a capacitor bank For an internal fuse capacitor bank the element failure bran...

Page 1135: ...rt value If the compensated unbalance current in one or more phases exceeds the set Start value the Level detector 1 module sends the enabling signal to the Timer 1 module Timer 1 Once activated the Timer 1 module activates the START output Depending on the value of the Operating curve type setting the time characteristics are according to DT or IDMT When the operation timer has reached the value ...

Page 1136: ... time the ALARM output is activated If the fault disappears before the alarm activates the alarm timer is reset immediately Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizo...

Page 1137: ...ction is usually used along with the three phase capacitor bank overload protection function to increase the sensitivity of protection for capacitor banks Due to the two stage operation and alarm stage unbalance protection and the natural unbalance compensation facility the protection of capacitor banks with internal fuses can be implemented with a very high degree of sensitivity The unbalance pro...

Page 1138: ... The capacitor bank compensated unbalance current I_COM_AMPL is observed from Monitored data 4 The command Record unbalance must be activated by selecting the value Record which stores the unbalance reference for future unbalance calculations 5 The compensated unbalance current I_COM_AMPL is re checked to be approximately zero The natural unbalance recording should be made only during the steady s...

Page 1139: ...ameter Values Range Unit Step Default Description Start value 0 01 1 00 xIn 0 01 0 10 Start value Alarm start value 0 01 1 00 xIn 0 01 0 05 Alarm start value Time multiplier 0 05 15 00 0 01 1 00 Time multiplier in IEC ANSI IDMT curves Operating curve type 1 ANSI Ext inv 2 ANSI Very inv 3 ANSI Norm inv 4 ANSI Mod inv 5 ANSI Def Time 6 L T E inv 7 L T V inv 8 L T inv 9 IEC Norm inv 10 IEC Very inv 1...

Page 1140: ... 0 00000 0 71200 0 00001 0 12170 Parameter B for customer program mable curve Curve parameter C 0 02 2 00 0 01 2 00 Parameter C for customer program mable curve Curve parameter E 0 0 1 0 0 1 1 0 Parameter E for customer program mable curve Table 1084 HCUBPTOC Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time Minimum o...

Page 1141: ...AT32 179 00 179 00 deg Compensated unbal ance current angle phase C HCUBPTOC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status IL1 unb 1 FLOAT32 0 00 5 00 xIn Measured unbalance current amplitude phase A IL2 unb 1 FLOAT32 0 00 5 00 xIn Measured unbalance current amplitude phase B IL3 unb 1 FLOAT32 0 00 5 00 xIn Measured unbalance current amplitude phase C 4 12 3 10 Technical data Table 1086 H...

Page 1142: ...ction block Figure 638 Function block symbol 4 12 4 3 Functionality The shunt capacitor bank switching resonance protection current based function SRCPTOC is used for detecting three phase resonance caused by capacitor switching or topology changes in the network The operating characteristic is a definite time DT SRCPTOC contains a blocking functionality It is possible to block function outputs ti...

Page 1143: ...mer 2 Figure 639 Functional module diagram Resonance current calculation This module calculates the resonance current per phase set as per setting Tuning harmonic Num The resonance current for phase A is calculated with the equation I RESO A I I I I RMS A A DC A K A _ _ _ _ _ _ 2 1 2 2 2 Equation 289 I RMS_A RMS value of current in phase A contains up to 11 th harmonic I DC_A DC component in phase...

Page 1144: ...ilter branch the resonance protection is very important In this case the setting Tuning harmonic Num should be set to 1 because the capacitor branch is not tuned for a special frequency as in tuned filter applications Even though Tuning harmonic Num is set to 1 the fundamental component is subtracted only once from I RMS Level detector 1 The maximum calculated resonance current is compared to the ...

Page 1145: ...on timer is frozen to the prevailing value In the Block all mode the whole function is blocked and the timers are reset In the Block OPERATE output mode SRCPTOC operates normally but the OPERATE output is not activated 4 12 4 6 Application Switched shunt capacitor banks are widely used by utilities and customers in industrial distribution systems to provide voltage support and to improve the power...

Page 1146: ...ensure that the function does not include thr tuned harmonic frequency current into the calculation of the resonance current If there is more than one harmonic filter bank involved each SRCPTOC tunes to the harmonic frequency of its corresponding filter bank The interlinking between the functions can be done in such a way that if resonance occurs in a higher harmonic frequency filter bank all the ...

Page 1147: ...ues Range Unit Step Default Description Alarm start value 0 03 0 50 xIn 0 01 0 03 Alarm limit for fil tered harmonic cur rents Start value 0 03 0 50 xIn 0 01 0 03 Tripping limit for filtered harmonic currents indicating resonance condi tion Tuning harmonic Num 1 11 1 11 Tuning frequency harmonic number of the filter branch Operate delay time 120 360000 ms 1 200 Operate delay time for resonance Ala...

Page 1148: ... accuracy 3 of the set value or 0 002 In for 2nd order Harmonics 1 5 of the set value or 0 002 In for 3rd order Harmonics 10th order 6 of the set value or 0 004 In for Harmonics 10th order Reset time Typically 45 ms or maximum 50 ms Retardation time Typically 0 96 Retardation time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20 ms Suppression of harmonics 50 dB at f fn...

Page 1149: ... block function outputs the definite timer or the function itself 4 12 5 4 Analog channel configuration CNUPTOV has three analog group inputs which must be properly configured Table 1094 Analog inputs Input Description U3P Three phase voltages URES Residual voltage measured or calculated UNEUT Measured neutral voltage See the preprocessing function blocks in this document for the possible signal s...

Page 1150: ...l module diagram Natural unbalance compensation This module calculates the natural unbalance compensation Calculation for compensation is initiated through the command Record unbalance available under the menu path Control CNUPTOV The function equates the operating signal to zero and calculates Uunb from the available known quantities Uunb is memorized as U m unb This memorized value is then used ...

Page 1151: ...view Blocking logic There are three operation modes in the blocking function The operation modes are controlled by the BLOCK input and the global setting in Configuration System Blocking mode which selects the blocking mode The BLOCK input can be controlled by a binary input a horizontal communication input or an internal signal of the protection relay s program The influence of the BLOCK signal a...

Page 1152: ...l UNeutral and for UN_pr and UN_sr are set in the global setting under Configuration Analog inputs Voltage Uo VT The operating signal setting is given as multiple of the neutral VT rated voltage In monitored data xUn refers to neutral VT rated voltage 4 12 5 7 Application Shunt capacitor banks are provided with an unbalance protection function which is mainly used to detect problems within capacit...

Page 1153: ...ge changes in case of failure of some phase elements of the ungrounded SCB UA UB UC UN Z Z Z IA IB IC IA IB IC 0 Figure 646 Ungrounded SCB In a healthy ungrounded capacitor bank the sum of the phase currents is I I I A B C 0 Figure 647 Equation If the capacitor bank is symmetrical that is there is equal impedance in each phase the equation can be U U Z U U Z U U Z A N B N C N 0 Figure 648 Equation...

Page 1154: ...he voltage rating of a neutral VT is 20 kV 100 V then in per unit terms refer to neutral side the neutral voltage is around 0 01 Un that is Start value should be set around 0 01 In addition assume that residual voltage terminal side is measured directly using an open delta VT having ratio of 20 3 100 3 100 3 kV V V Also the Primary voltage and Secondary voltage settings under Configuration Analog ...

Page 1155: ... Operate delay time 100 300000 ms 100 100 Operate delay time Table 1099 CNUPTOV Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 1100 CNUPTOV Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time 4 12 5 10 CNUPTOV Monitored data Table 1101 CNUPT...

Page 1156: ...um 1 on 2 blocked 3 test 4 test blocked 5 off Status 4 12 5 11 Technical data Table 1102 CNUPTOV Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured voltage fn 2 Hz 1 5 of the set value or 0 002 Un Start time 1 2 UFault 1 1 set Start value Typically 75 ms Reset time Typically 40 ms Reset ratio Typically 0 96 Retardation time 35 ms Operate time accuracy...

Page 1157: ...ormer inrush detection is based on the following principle the output signal BLK2H is activated once the numerically derived ratio of second harmonic current I_2H and the fundamental frequency current I_1H exceeds the set value The operate time characteristic for the function is of definite time DT type The function contains a blocking functionality Blocking deactivates all outputs and resets time...

Page 1158: ...H_A I_1H_A I_2H_C I_1H_C Level detector t Timer AND t Timer AND I3P I_1H_A I_1H_B I_1H_C I_2H_A I_2H_B I_2H_C AND Phase selection logic I_1H_A I_1H_B I_1H_C Figure 657 Functional module diagram I_2H I_1H These modules calculate the ratio of the second harmonic I_2H and fundamental frequency I_1H of the phase currents The calculated value is compared to the set Start value If the calculated value e...

Page 1159: ...ating the BLK2H output If Num of start phases 1 out of 3 an inrush on any of the phases activates output BLK2H If the set value equals 2 out of 3 an inrush or at least two phases are required to activate output BLK2H 5 1 6 Application Transformer protections require high stability to avoid tripping during magnetizing inrush conditions A typical example of an inrush detector application is doubling...

Page 1160: ... available 5 1 7 Signals 5 1 7 1 INRPHAR Input signals Table 1104 INRPHAR Input signals Name Type Default Description I3P SIGNAL Three phase currents BLOCK BOOLEAN 0 False Block input status 5 1 7 2 INRPHAR Output signals Table 1105 INRPHAR Output signals Name Type Description BLK2H BOOLEAN Second harmonic based block Protection related functions 1MRS759142 F 1160 REX640 Technical Manual ...

Page 1161: ...t Description Operation 1 on 5 off 1 on Operation Off On Table 1109 INRPHAR Non group settings Advanced Parameter Values Range Unit Step Default Description Num of start pha ses 1 1 out of 3 2 2 out of 3 1 1 out of 3 Number of phases required for oper ate activation Reset delay time 0 60000 ms 1 20 Reset delay time 5 1 9 INRPHAR Monitored data Table 1110 INRPHAR Monitored data Name Type Values Ran...

Page 1162: ...ommands are either internal commands to the terminal or external commands through binary inputs The start command is always a default for three phase operation CCBRBRF includes a three phase conditional or unconditional retrip function and also a three phase conditional back up trip function CCBRBRF uses the same levels of current detection for both retrip and back up trip The operating values of ...

Page 1163: ... error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 5 2 5 Operation principle The function can be enabled and disabled with the Operation setting The corre...

Page 1164: ...urrent at phase to earth faults is normally much smaller than the short circuit currents To detect a breaker failure at single phase earth faults in these systems it is necessary to measure the residual current separately In effectively earthed systems also the setting of the earth fault current protection can be chosen at a relatively low current level The current setting should be chosen in acco...

Page 1165: ...rrents drop below Current val ue setting 1 out of 4 Either of the following is true CB is in open position All phase currents drop below Current val ue setting and the residual current drops below Current value Res setting 2 out of 4 One of the following is true CB is in open position All phase currents drop below Current val ue setting The residual current drops below Current value Res setting an...

Page 1166: ...l sensitive AND START AND OR CB failure trip mode 1 out of 3 CB failure trip mode 2 out of 4 AND OR AND AND AND OR CB failure mode Both AND CB failure mode Both OR AND OR I From Level detector 1 AND I0 From Level detector 2 2 or 3 ph 1 ph Figure 661 Start logic Timer 1 Once activated the timer runs until the set Retrip time value has elapsed The time characteristic is according to DT When the oper...

Page 1167: ... ability to maintain transient stability in case of a fault close to a power plant Figure 662 Timeline of the breaker failure protection Timer 3 This module is activated by the CB_FAULT signal Once activated the timer runs until the set CB fault delay value has elapsed The time characteristic is according to DT When the operation timer has reached the maximum time value CB fault delay the CB_FAULT...

Page 1168: ...er 1 elapses and CB is in closed position Both AND TRRET is activated after Timer 1 elapses and CB is in closed position and any phase cur rent exceeds Current value setting Both OR TRRET is activated after Timer 1 elapses and either of the following is true CB is in closed position Any phase current exceeds Current value setting TRRET activation is blocked if either CB_FAULT_AL output from Timer ...

Page 1169: ...dge of the START input detected and CB_FAULT_AL are both active The operation of Backup trip logic depends on the settings CB failure mode and CB failure trip mode as shown in Table 1115 Table 1115 Backup trip logic operation Value of setting CB failure mode Value of setting CB failure trip mode Conditions for activating Backup trip logic Current 1 out of 3 Any phase current exceeds Current value ...

Page 1170: ...Current value Res setting Two or three phase currents exceed Cur rent value setting Both OR 1 out of 3 Either of the following is true CB is in closed position Any phase current exceeds Current value setting 1 out of 4 One of the following is true CB is in closed position Any phase current exceeds Current value setting The residual current exceeds Current val ue Res setting 2 out of 4 One of the f...

Page 1171: ...ent in the fault clearance system For practical and economical reasons it is not feasible to duplicate the circuit breaker for the protected component but breaker failure protection is used instead The breaker failure function issues a backup trip command to up stream circuit breakers in case the original circuit breaker fails to trip for the protected component The detection of a failure to break...

Page 1172: ...p are available When a retrip with current check is chosen the retrip is performed only if there is a current flow through the circuit breaker The backup trip timer is also initiated at the same time as the retrip timer If CCBRBRF detects a failure in tripping the fault within the set backup delay time which is longer than the retrip time it sends a backup trip signal to the chosen backup breakers...

Page 1173: ...18 CCBRBRF Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Current value 0 05 2 00 xIn 0 01 0 30 Operating phase current Current value Res 0 05 2 00 xIn 0 01 0 30 Operating residual current CB failure trip mode 1 2 out of 4 2 1 out of 3 3 1 out of 4 2 1 out of 3 Backup trip current check mode CB failure mode 1 Current 2 Break...

Page 1174: ... Unit Description CCBRBRF Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 5 2 10 Technical data Table 1121 CCBRBRF Technical data Characteristic Value Operation accuracy Depending on the frequency of the meas ured current fn 2 Hz 1 5 of the set value or 0 002 In Operate time accuracy 1 0 of the set value or 20 ms Reset time 20 ms Retardation time 20 ms 5 2 11 Technical revision history Tabl...

Page 1175: ...features of this function influence the trip signal behavior of the circuit breaker The minimum trip pulse length can be set when the non latched mode is selected It is also possible to select the latched or lockout mode for the trip signal 5 3 4 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off When the TRPPTR...

Page 1176: ...TRPPTRC is provided with possibilities to activate a lockout When activated the lockout can be manually reset after checking the primary fault by activating the RST_LKOUT input or from the LHMI clear menu parameter When using the Latched mode the resetting of the TRIP output can be done similarly as when using the Lockout mode It is also possible to reset the Latched mode remotely through a separa...

Page 1177: ...2 are different Therefore even if all references are made only to TRPPTRC1 they also apply to TRPPTRC2 The inputs from the protection functions are connected to the OPERATE input Usually a logic block OR is required to combine the different function outputs to this input The TRIP output is connected to the binary outputs on the IO board This signal can also be used for other purposes within the pr...

Page 1178: ...aker lockout out put set until reset 5 3 7 TRPPTRC Settings Table 1126 TRPPTRC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Trip pulse time 20 60000 ms 1 250 Minimum duration of trip output sig nal Trip output mode 1 Non latched 2 Latched 3 Lockout 1 Non latched Select the opera tion mode for trip output 5 3 8 TRPPTRC Moni...

Page 1179: ...umans and properties people can touch or get close to conductors carrying large amounts of energy ABB has developed a patented technology US Patent 7 069 116 B2 June 27 2006 US Patent 7 085 659 B2 August 1 2006 to detect a high impedance fault The high impedance fault detection function PHIZ also contains a blocking functionality It is possible to block function outputs if desired 5 4 4 Analog cha...

Page 1180: ...uld make the system operate more dependably for high impedance faults in the line but the operation is more likely for other transients in the system There are events in electrical networks which can cause similar current waveforms like high impedance faults These events could then be detected by the PHIZ algorithm causing unnecessary detections Normally electrical network operator does not know t...

Page 1181: ...n harmonic components within the available data window can play a vital role in the high impedance fault detection A major challenge is to develop a data model that acknowledges that high impedance faults could take place at any time within the observation window of the signal and could be delayed randomly and attenuated substantially The model is motivated by extensive research actual experimenta...

Page 1182: ...y high fault current However a small percentage of the earth faults have a very large impedance They are comparable to load impedance and consequently have very little fault current These high impedance faults do not pose imminent danger to power system equipment However they are a considerable threat to people and property The IEEE Power System Relay Committee working group on High Impedance Faul...

Page 1183: ...ERATE BOOLEAN Operate 5 4 8 PHIZ Settings Table 1131 PHIZ Group settings Basic Parameter Values Range Unit Step Default Description Security Level 1 10 1 5 Security Level Table 1132 PHIZ Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On System type 1 Grounded 2 Ungroun ded 1 Grounded System Type 5 4 9 PHIZ Monitored data Table ...

Page 1184: ... and remote end line differential protection relays The function includes eight binary signals that are transferred in the protection communication telegram and can be freely configured and used for any purpose in the line differential application BSTGAPC transfers binary data continuously over the protection communication channel between the terminals Each of the eight signals are bidirectional a...

Page 1185: ...nds Figure 677 Functional module diagram Binary signal send The status of the inputs is continuously sent in the line differential protection telegrams SEND_SIG_A can be used for alarming based on the status of SEND_SIG_1 8 By selecting the signal mode as In use alarm sel the sending status of the corresponding signal affects also the activation criteria of SEND_SIG_A Further in case more than one...

Page 1186: ...e binary signals vary depending on the usage of the data When the binary data is used as blocking signals for the line differential protection the transfer response is extremely high Binary signal interchange can be used in applications such as Remote position indications Inter tripping of the circuit breakers on both line ends Blocking of the line differential protection during transformer inrush...

Page 1187: ...without the need to configure GOOSE This minimizes the configuration effort since configuration templates can be directly used when signal transfer is required only for point to point instead of multipoint In addition to X6 Ethernet port which is tied to PCSITPC1 and BSTGAPC1 2 X3 Ethernet port can be configured to dedicated channel mode It also requires PCSITPC2 block for supervision and one of t...

Page 1188: ...RECV_SIG_5 BOOLEAN Receive signal 5 state RECV_SIG_6 BOOLEAN Receive signal 6 state RECV_SIG_7 BOOLEAN Receive signal 7 state RECV_SIG_8 BOOLEAN Receive signal 8 state SEND_SIG_A BOOLEAN Binary signal transfer sending alarm state RECV_SIG_A BOOLEAN Binary signal transfer receive alarm state 5 5 7 Settings Table 1136 BSTGAPC Group settings Basic Parameter Values Range Unit Step Default Description ...

Page 1189: ...for received signal 3 Pulse time 4 0 60000 ms 1 0 Minimum pulse time for received signal 4 Pulse time 5 0 60000 ms 1 0 Minimum pulse time for received signal 6 Pulse time 6 0 60000 ms 1 0 Minimum pulse time for received signal 6 Pulse time 7 0 60000 ms 1 0 Minimum pulse time for received signal 7 Pulse time 8 0 60000 ms 1 0 Minimum pulse time for received signal 8 Table 1137 BSTGAPC Non group sett...

Page 1190: ...ting of the motor After the emergency start input is activated the motor can be started normally ESMGAPC itself does not actually restart the motor The function contains a blocking functionality It is possible to block function outputs timer or the function itself 5 6 4 Analog channel configuration ESMGAPC has one analog group input which must be properly configured Table 1139 Analog inputs Input ...

Page 1191: ...a standstill condition The ST_EMERG_ENA output remains active for 10 minutes or as long as the ST_EMERG_RQ input is high whichever takes longer The activation of the BLOCK input blocks and also resets the timer The function also provides the ST_EMERG_ENA output change date and time T_ST_EMERG The information is available in the monitored data view 5 6 6 Application If the motor needs to be started...

Page 1192: ...e Emergency start in put 5 6 7 2 ESMGAPC Output signals Table 1141 ESMGAPC Output signals Name Type Description ST_EMERG_ENA BOOLEAN Emergency start 5 6 8 ESMGAPC Settings Table 1142 ESMGAPC Group settings Advanced Parameter Values Range Unit Step Default Description Motor standstill A 0 01 0 20 xIn 0 01 0 12 Current limit to check for motor standstill condition Table 1143 ESMGAPC Non group settin...

Page 1193: ...fn 1 5 of the set value or 0 002 Un 5 6 11 Technical revision history Table 1146 ESMGAPC Technical revision history Product connectivi ty level Technical revision Change PCL4 E Setting Motor standstill A minimum value changed from 0 05xIn to 0 01xIn 5 7 Fault locator SCEFRFLO ANSI FLOC 5 7 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 devic...

Page 1194: ...e fault distance calculation is based on the locally measured fundamental frequency current and voltage phasors The full operation of SCEFRFLO requires all phase currents and phase to earth voltages to be measured The fault distance estimate is obtained when SCEFRFLO is externally or internally triggered 5 7 4 Analog channel configuration SCEFRFLO has three analog group inputs which must be proper...

Page 1195: ...ation setting The corresponding parameter values are on and off The operation of SCEFRFLO can be described with a module diagram All the modules in the diagram are explained in the next sections BLOCK TRIGG_T Phase selection logic Fault impedance and distance calculation TRIGG_REC ALARM Trigger detection Alarm indication I3P I_A I_B I_C U3P URES U_A_AB U2 U1 U0 U_B_BC U_C_CA Recorded data TRIGG_XC...

Page 1196: ...s and corresponding fault loops Fault type Description Flt loop No fault No fault A E Phase A to earth fault AG Fault B E Phase B to earth fault BG Fault C E Phase C to earth fault CG Fault A B Phase A to B short circuit fault AB Fault B C Phase B to C short circuit fault BC Fault C A Phase C to A short circuit fault AC Fault A B C E Three phase short circuit ABC Fault In case of two phase to eart...

Page 1197: ...imary ohms The composition of this term is different for short circuit and earth faults loops as described in the following subsections These impedance values can be used as such or they can be further processed in system level fault location applications such as distribution management system DMS 5 7 5 3 Fault loops AG Fault or BG Fault or CG Fault Fault loops AG Fault BG Fault and CG Fault are u...

Page 1198: ...In all other cases of system neutral point earthing effectively earthed low resistance low reactance or unearthed networks setting Non comp should be selected Earth fault distance calculation in case of non compensated networks In case of non compensated networks effectively earthed low resistance lowreactance or unearthed networks the setting Flt Loc Det mode is equal to Noncomp Furthermore the e...

Page 1199: ...ted load Equivalent load Dis 0 5 When the load is tapped at the end of the feeder Equivalent load Dis 1 0 If the load distribution is unknown a default value of 0 5 can be used for Equivalent load Dis The maximum value of the voltage drop denoted as Udrop real appears at the end of the feeder The Equivalent load Dis setting is the distance at which a single load tap corresponding to the total load...

Page 1200: ...ictions the Load modelling algorithm can also be applied to unearthed networks In this case the EF algorithm Cur Sel setting should be set to Io based and thus Ph capacitive React and Ph leakage Ris settings must be determined The prerequisite for the operation of SCEFRFLO in earth faults in unearthed networks is that the earth fault current of the network corresponding to a solid fault exceeds th...

Page 1201: ...fault Timing t0 is common to both triggering types Calculation Trg mode either Internal or External Pre fault indicating healthy network phasors are continuously updated and stored at intervals of 300 ms until the earth fault is indicated When the earth fault is detected internal detection the pre fault phasor is stored at least 300 ms before the detection of the earth fault This time instance bef...

Page 1202: ...hange to setting Zero Ris Curr change Time instance t1 is taken at least one fundamental cycle before and t2 at least one fundamental cycle after the change in the resistive component of Io exceeding the start value setting Zero Ris Curr change The value for setting Zero Ris Curr change should be chosen based on the rated current value of the parallel resistor with proper margin Zero Ris Curr chan...

Page 1203: ... rising edge TRIGG_T t1 t1 t2 t2 Time delay t0 t0 Figure 685 Fault distance estimate triggering moment definitions Fault loops AB Fault BC Fault or CA Fault Fault loops AB Fault BC Fault or CA Fault are used for phase to phase short circuit faults as well as in the case of a two phase to earth fault if the individual earth faults are located at the same feeder Figure 686 shows the phase to phase f...

Page 1204: ... is most accurate when calculated with the fault loop model This model requires positive sequence impedances of the protected feeder to be given as settings If these settings are not available valid impedance values can be calculated also without the fault loop model with setting Enable simple model Enabled However a valid distance estimate that is the conversion of measured impedance electrical f...

Page 1205: ... calculation is most accurate when the calculation is made with the fault loop model This model requires positive sequence impedances of the protected feeder to be given as settings If these settings are not available valid impedance values can be calculated also without the fault loop model with setting Enable simple model Enabled However a valid distance estimate that is the conversion of measur...

Page 1206: ... on fault distance estimation For earth faults the load compensation is done automatically inside the fault distance calculation algorithm For short circuit faults load compensation is enabled with setting Load Com PP loops The default value is Enabled The parameter should be set to Disabled only if the ratio between the expected fault current and load current is high or when the fault distance es...

Page 1207: ...A B and C Each section is enabled by entering a section length which ranges from zero to settings Line Len section A Line Len section B or Line Len section C in the order section A section B section C The earth fault loops require both positive sequence and zero sequence impedances for example R1 line section A and X1 line section A R0 line section A and X0 line section A For the short circuit loo...

Page 1208: ...and y r radius m for single conductor Figure 689 Typical distribution line tower configurations Example values of positive sequence impedances for typical medium voltage overhead lines are given in the following tables Table 1152 Positive sequence impedance values for typical 11 kV conductors Flat tower configuration Name R1 Ω km X1 Ω km ACSR 50 SQ mm 0 532 0 373 ACSR 500 SQ mm 0 0725 0 270 Table ...

Page 1209: ...typically known or can easily be obtained from data sheets The zero sequence values are generally not as easy to obtain as they depend on the actual installation conditions and configurations Sufficient accuracy can however be obtained with rather simple calculations using the following equations which apply per phase for symmetrically transposed three phase aluminium overhead lines without ground...

Page 1210: ...ct setting represents the total phase to earth capacitive reactance of the protected feeder per phase Based on experience a proper estimate for Ph leakage Ris should be about 20 40 Ph capacitive React Figure 690 Equivalent diagram of the protected feeder R L0F Ph leakage Ris The determination of the Ph capacitive React setting can be based either on network data or measurement If the total phase t...

Page 1211: ... fault is detected by the residual overvoltage function START of ROVPTOV but not seen by the forward looking earth fault protection function START of DEFLPDEF the fault is located outside the protected feeder This is mandatory for valid measurement of setting Ph capacitive React After a set delay TONGAPC the input TRIGG_XC0F is activated and the parameter XC0F Calc in the recorded data is updated ...

Page 1212: ...geneous line when the protected feeder consists of two types of conductors The impedance model with three line sections is enabled by setting Line Len section A Line Len section B and Line Len section C to differ from zero In this case the impedance settings R1 line section A X1 line section A R0 line section A X0 line section A R1 line section B X1 line section B R0 line section B X0 line section...

Page 1213: ... section A 10 000 pu 4 000 pu R1 line section B N A 0 536 Ω pu X1 line section B N A 0 369 Ω pu Line Len section B 0 000 pu 3 000 pu R1 line section C N A 1 350 Ω pu X1 line section C N A 0 398 Ω pu Line Len section C 0 000 pu 3 000 pu Figure 692 illustrates the error when converting the measured fault loop reactance into physical fault distance The fault location is varied from 1 km to 10 km in 1...

Page 1214: ...is important that triggering be timed suitably to provide sufficient time for the distance estimation calculation before tripping of the feeder circuit breaker In case of internal triggering the TRIGG_REC input is not used for triggering Instead the trigger signal is created internally so that the estimation is started when Phase selection logic detects a fault and the estimate is triggered when i...

Page 1215: ...indication SCEFRFLO contains an alarm output for the calculated fault distance If the calculated fault distance FLT_DISTANCE is between the settings Low alarm Dis limit and High alarm Dis limit the ALARM output is activated If setting High alarm Dis limit has been set below Low alarm Dis limit the ALARM operation is inverted the ALARM output is activated if High alarm Dis limit is undershot or Low...

Page 1216: ...LOOP Flt distance FLT_DISTANCE Flt Dist quality FLT_DIST_Q Flt loop resistance RFLOOP Flt loop reactance XFLOOP Flt phase reactance XFPHASE Flt point resistance RF Flt to Lod Cur ratio IFLT_PER_ILD Equivalent load Dis S_CALC XC0F Calc XC0F_CALC 5 7 6 Measurement modes The full operation of SCEFRFLO requires that all three phase to earth voltages are measured The voltages can be measured with conve...

Page 1217: ... of distribution networks Earth faults can be located in effectively earthed and low resistance low reactance earthed networks With certain limitations SCEFRFLO can also be used for locating an earth fault in unearthed distribution networks Configuration example A typical configuration example for SCEFRFLO triggering is illustrated in Figure 691 where external triggering is applied that is Calcula...

Page 1218: ...ype Description ALARM BOOLEAN Fault location alarm signal 5 7 9 SCEFRFLO Settings Table 1159 SCEFRFLO Group settings Basic Parameter Values Range Unit Step Default Description Flt Loc Det mode 2 Non comp 1 Comp switched R 2 Non comp Fault location de tection mode Z Max phase load 1 0 10000 0 ohm 0 1 80 0 Impedance per phase of max load overcurr un der imp PSL Ph leakage Ris 20 1000000 ohm 1 210000...

Page 1219: ...nce line reactance line section B R0 line section B 0 000 1000 000 ohm pu 0 001 4 000 Zero sequence line resistance line sec tion B X0 line section B 0 000 1000 000 ohm pu 0 001 4 000 Zero sequence line reactance line sec tion B Line Len section B 0 000 1000 000 pu 0 001 0 000 Line length section B R1 line section C 0 000 1000 000 ohm pu 0 001 1 000 Positive sequence line resistance line section C...

Page 1220: ...s tance estimate 5 7 10 SCEFRFLO Monitored data Table 1163 SCEFRFLO Monitored data Name Type Values Range Unit Description RF FLOAT32 0 00 3000 00 ohm Fault point resistance in primary ohms FAULT_LOOP Enum 1 AG Fault 2 BG Fault 3 CG Fault 4 AB Fault 5 BC Fault 6 CA Fault 7 ABC Fault 5 No fault Fault impedance loop FLT_DISTANCE FLOAT32 0 00 3000 00 pu Fault distance in units selected by the user FL...

Page 1221: ... phase A magnitude A Pre Flt Phs A Angl FLOAT32 180 00 180 00 deg Pre fault current phase A angle A Pre Flt Phs B Magn FLOAT32 0 00 40 00 xIn Pre fault current phase B magnitude A Pre Flt Phs B Angl FLOAT32 180 00 180 00 deg Pre fault current phase B angle A Pre Flt Phs C Magn FLOAT32 0 00 40 00 xIn Pre fault current phase C magnitude A Pre Flt Phs C Angl FLOAT32 180 00 180 00 deg Pre fault curren...

Page 1222: ...gnitude V Flt Phs B angle FLOAT32 180 00 180 00 deg Fault voltage phase B angle V Flt Phs C Magn FLOAT32 0 00 40 00 xUn Fault voltage phase C magnitude V Flt Phs C angle FLOAT32 180 00 180 00 deg Fault voltage phase C angle 5 7 11 Technical data Table 1164 SCEFRFLO Technical data Characteristic Value Measurement accuracy At the frequency f fn Impedance 2 5 or 0 25 Ω Distance 2 5 or 0 16 km 0 1 mil...

Page 1223: ...ry required for a correct directional measurement is not available 5 8 4 Analog channel configuration CVPSOF has two analog group inputs which must be properly configured Table 1165 Analog inputs Input Description I3P 1 Three phase currents necessary when Operation mode is other than Start U3P 2 Three phase voltages necessary when Operation mode is other than Start See the preprocessing function b...

Page 1224: ...ction relay once the mismatch is corrected 5 8 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The operation of CVPSOF can be described by using a module diagram All the modules in the diagram are explained in the next sections OPERATE START Trigger SOTF control Dead line detector START_DLYD CB_CL_CMD SOTF ...

Page 1225: ...uts The dead line con dition is signalled to the SOTF control after the delay defined with the Dead line time setting Current The dead line detection function is enabled and based sole ly on the undercurrent condition A dead line condition is declared if all the phase currents are below the Current dead Lin Val setting The dead line is detected if the dead line condition is declared and simultaneo...

Page 1226: ... after a signal from the trigger module This indicates that the breaker is closed onto fault Current Voltage The OPERATE output is activated immediately after a signal from the SOTF detection module This indicates that the breaker is closed onto fault This operation mode can be used for example if the non directional distance zone is not available Both The OPERATE output is activated immediately a...

Page 1227: ...he feeder is considerably higher than the maximum load currents it is possible that the whole feeder length is covered by CVPSOF tripping If it is required to delay the tripping for example due to high inrush currents the starting signal can be connected to the START_DLYD input instead The Current dead Lin Val setting parameter is set to 20 percent of the base current by default The parameter must...

Page 1228: ...170 CVPSOF Output signals Name Type Description OPERATE BOOLEAN Operate 5 8 8 CVPSOF Settings Table 1171 CVPSOF Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Table 1172 CVPSOF Non group settings Advanced Parameter Values Range Unit Step Default Description Operation mode 1 Start 2 Current voltage 3 Both 3 Both Mode of opera...

Page 1229: ... for volt age and current based detection Operate time delay 0 120000 ms 10 20 Delay for the de layed start input SOTF reset time 0 60000 ms 10 1000 SOTF detection pe riod after initializa tion Dead line time 0 60000 ms 10 200 Delay time for acti vation of dead line detection 5 8 9 CVPSOF Monitored data Table 1173 CVPSOF Monitored data Name Type Values Range Unit Description CVPSOF Enum 1 on 2 blo...

Page 1230: ...vice number Local acceleration logic DSTPLAL LAL 21LAL 5 9 2 Function block Figure 698 Function block 5 9 3 Functionality The local acceleration logic function DSTPLAL is a complementary function to the distance protection function DSTPDIS DSTPLAL is not intended for a stand alone use The main purpose of DSTPLAL is to achieve a fast fault clearing which is independent of the fault location on the ...

Page 1231: ...ssing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 5 9 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are on and off The operation of DSTPLAL can be described with a module diagram All the modules in the diagram are explained in the next sections Zone ext...

Page 1232: ...READY input The start signal from the non directional zone is connected to the NONDIR_ST input If the non directional zone is not available for this then the start output from the overreaching zone with the biggest reach or GFC can be used instead The permission for zone acceleration is given if AR_READY TRUE that is the AR function is ready to start a new AR sequence If the set reclaim time of th...

Page 1233: ...iagram of Loss of load logic Initialization The Initialization module gives an enabling signal to the Trip logic module when the values of all three phase currents are above the set value of Load current value for more than the time set with Load release on time The enabling signal has a drop off delay defined with the Load release off Tm setting Loss of load current detection The Loss of load cur...

Page 1234: ...ault is still present after these shots further tripping is delayed in accordance with the other zones so that the operation becomes slower than the protection of the load taps enabling it to clear The final tripping that ends the sequence is always performed selectively according to the time grading of the zones If the fault is located on the adjacent feeder or bus within the reach of the overrea...

Page 1235: ...ls Table 1176 DSTPLAL Input signals Name Type Default Description I3P SIGNAL Three phase currents BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode AR_READY BOOLEAN 0 False Autoreclosure ready releases function used for fast trip CB_CL_CMD BOOLEAN 0 False CB close command EX_ACC BOOLEAN 0 False Connected to func tion used for tripping at zone extension LOSSLOAD_ACC BOOLEAN 0 Fal...

Page 1236: ...one extension 2 Loss of load 3 Both 3 Both Operation mode Load release on time 0 60000 ms 10 0 Time delay on pick up for load current release 5 9 9 DSTPLAL Monitored data Table 1179 DSTPLAL Monitored data Name Type Values Range Unit Description DSTPLAL Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 5 9 10 Technical data Table 1180 DSTPLAL Technical data Characteristic Value Operation accur...

Page 1237: ...ional comparison blocking scheme DCB The directional comparison unblocking scheme DCUB can also be implemented by complementing the permissive schemes with an additional logic called the unblocking function which is also included in DSOCPSCH If the permissive overreach scheme is used some of the power system conditions require additional special logic circuits such as the current reversal and weak...

Page 1238: ...ected with the Scheme type setting Table 1181 Communication scheme based on the Scheme type value Scheme type value Communication scheme Intertrip DUTT Permissive Underreach PUTT Permissive Overreach POTT Blocking DCB The unblocking scheme DCUB is enabled with the Unblock Mode setting Multiplexer The multiplexer connects an input signal to an output based on the value of the Scheme type setting Pr...

Page 1239: ...ed activation of the OPERATE output with the carrier received CS_INTER_TR signal after a settable pick up delay Coordination Time has elapsed without further local criteria The unblocking function Unblock Mode Permanent and Unblock Mode Time window must not be enabled with the DUTT scheme as the lost guard signal results in an immediate trip of the local circuit breaker The activation of the BLOCK...

Page 1240: ... CB_B Z2_START TRIP_CB_A TRIP_CB_B Z1_START Z2_START 3 3 Figure 705 Simplified functional diagram of the permissive underreach scheme Permissive overrreaching transfer trip scheme POTT The permissive overreach scheme is enabled with Scheme type Permissive Overreach In this scheme the start signal from the overreaching zone Z2 is connected to the CSOR input to create a CS_PRM signal The CS_PRM sign...

Page 1241: ...rom the reverse looking zone Z3 is connected to the CSBLK input to create a CS_BLOCKING signal The starting of the reverselooking zone indicates that the fault is located outside the protected feeder The duration of the CSBLK input signal can be prolonged with the Carrier Min Dur setting to ensure a sufficient duration of the CS_BLOCKING signal The blocking scheme is mainly used to allow the overr...

Page 1242: ...gnal is not sent because the fault is not sent as it is not seen by the reverse looking zones Z3 Z1 Z2 Z1 Z2 Z3 Z3 Z2_START TRIP_CB_A TRIP_CB_B Z2_START Bus A Bus B 3 3 Figure 707 Simplified functional diagram of the blocking scheme internal fault In Figure 708 in case of external faults the protection relay at bus B sees the fault in the reverse direction and sends a blocking signal CS_BLOCKING t...

Page 1243: ...e dependability of the permissive schemes is improved by using the loss of guard signal from the communication equipment to create a CRL output signal locally This enables the permissive scheme to operate even if the communication channel is interrupted or lost The unblocking function uses a carrier guard signal which must always be present The absence of the CRG signal for a time longer than the ...

Page 1244: ...erformance of DSOCPSCH is directly related to the communication channel speed and to the security against false or lost signals Therefore dedicated communication channels are recommended With short distances of up to a few kilometers a typical communication media is a simple pilot wire based on auxiliary power With distances of up to 50 km with the integrated communication interface or up to 150 k...

Page 1245: ...interval counting from the beginning of the interruption or for as long as the communication channel is lost This is achieved by connecting the supervision output of the implemented communication functionality to the dedicated carrier guard signal input of DSOCPSCH In general the unblocking scheme provides better security than the blocking scheme because tripping in external faults is only possibl...

Page 1246: ... must overlap to prevent a gap between the protection zones where the faults are not detected If the underreaching zone does not meet the required sensitivity for example the fault infeed from a remote end the blocking or permissive overreach scheme is considered To achieve an instantaneous trip the carrier received signal CR_PRM must be received when the overreaching zone Z2 is still starting In ...

Page 1247: ..._PRM signal from the underreaching zone must typically be prolonged In parallel feeder applications the scheme typically needs to be complemented by the current reversal logic To ensure the correct operation in this case the CS_PRM signal must not be prolonged Carrier Min Dur 0 s There is no need to delay the tripping while receiving the carrier signal so the timer Coordination Time is set to 0 Se...

Page 1248: ...RM signal is received Due to the absence of the CRG signal during the security time the Loss of carrier time setting is used as a CR_PRM signal This also enables a permissive scheme to operate when the communication channel is temporarily lost during an internal fault Setting guidelines for the unblocking scheme DCUB The unblocking function is configured with the Unblock Mode setting Unblock Mode ...

Page 1249: ...hing dis tance protection zone signal CR_PRM BOOLEAN 0 False Received teleprotec tion permissive from the other side CR_BLOCKING BOOLEAN 0 False Received teleprotec tion blocking from the other side CR_INTER_TR BOOLEAN 0 False Received direct trip from the other side CRG BOOLEAN 0 False Carrier guard signal received 5 10 6 2 DSOCPSCH Output signals Table 1184 DSOCPSCH Output signals Name Type Desc...

Page 1250: ...100 Minimum duration of a carrier send signal Coordination Time 0 60000 ms 1 35 Co ordination tim er for blocking scheme Table 1186 DSOCPSCH Non group settings Advanced Parameter Values Range Unit Step Default Description Unblock Mode 1 Off 2 Permanent 3 Time window 1 Off Operation mode of unblocking logic Loss of carrier time 0 60000 ms 1 35 Pickup security timer on loss of carrier guard signal 5...

Page 1251: ...clearing independent of the fault location on the protected feeder There are four available communication scheme types Direct underreaching transfer trip DUTT Permissive underreaching transfer trip PUTT Permissive overreaching transfer trip POTT Directional comparison blocking scheme DCB The directional comparison unblocking scheme DCUB can also be provided by complementing the permissive schemes ...

Page 1252: ...C CSOR BLK_CS_OPR CSBLK OPERATE DUTT PUTT POTT DCB CRL LCG OR OR CR_BLOCKING Multiplexer OR AND AND Figure 710 Functional module diagram The applied communication scheme logic in RESCPSCH is selected with the Scheme type setting Table 1189 Communication scheme based on the Scheme type value Scheme type value Communication scheme Intertrip DUTT Permissive Underreach PUTT Permissive Overreach POTT B...

Page 1253: ...an be prolonged by the Carrier Min Dur setting to ensure a sufficient duration for the CS_INTER_TR signal The local circuit breaker is directly tripped activation of the OPERATE output with the carrier received CS_INTER_TR signal after a settable pick up delay Coordination time has elapsed without further local criteria The unblocking function Unblock mode Permanent and Unblock mode Time window mu...

Page 1254: ...l start signal in the forward direction can also be connected to the CACC input The CS_PRM signal is also generated if the CR_PRM signal is received and the local carrier acceleration signal CACC is active Activating the BLOCK input totally blocks the permissive underreach scheme The CS_PRM and OPERATE outputs can be blocked by the BLK_CS_OPR input CB_A CB_B Z2_START TRIP_CB_A TRIP_CB_B DEFH_START...

Page 1255: ...tally blocks the permissive overreach scheme The CS_PRM and OPERATE outputs can be blocked by the BLK_CS_OPR input DEFH_START CB_A CB_B Z2_START DEFL_START TRIP_CB_A TRIP_CB_B Bus A Bus B 3 3 Figure 713 Simplified functional diagram of the permissive overreach scheme Directional comparison blocking scheme DCB The directional comparison blocking scheme is enabled with Scheme type Blocking In the bl...

Page 1256: ...must not be zero Activating the BLOCK input totally blocks the directional comparison blocking scheme The CS_PRM and OPERATE outputs can be blocked by the BLK_CS_OPR input In Figure 714 in case of internal faults the CS_BLOCKING signal is not sent as the fault is not seen by the reverse looking overreaching function DEFL_START Forward TRIP_CB_A TRIP_CB_B DEFL_START Forward Bus A Bus B 3 3 Figure 7...

Page 1257: ...oss of guard signal from the communication equipment to create a CRL output signal locally This enables the permissive scheme to operate even if the communication channel is interrupted or lost The unblocking function uses a carrier guard signal which must always be present The absence of the CRG signal for a time longer than the value of the Loss of carrier time setting generates a logical CRL si...

Page 1258: ...herefore dedicated communication channels are recommended With short distances of up to a few kilometers a typical communication media is a simple pilot wire based on auxiliary power With distances of up to 150 km fibre optic cables using digital data transmission can be used To avoid false signals that could cause unwanted operation the security of the communication channel should be emphasized A...

Page 1259: ...o the dedicated carrier guard signal input of RESCPSCH In general the unblocking scheme provides better security than the blocking scheme because tripping in external faults is only possible if the fault occurs within the fixed time interval after the beginning of the channel interruption The direct transfer trip scheme uses the underreaching function to trip the local breaker and to transfer the ...

Page 1260: ... activated The function also generates a CS_PRM signal by combining the carrier received CR_PRM signal from a remote end and also the local activation of CACC giving the permission to a remote function to trip instantaneously The CR_PRM signal must be received when the overreaching residual overcurrent protection is still active to achieve an instantaneous trip In some cases due to the fault curre...

Page 1261: ...urity can cause unwanted tripping for external faults Inadequate speed or dependability can cause delayed tripping for internal faults In the permissive overreaching scheme the CS_PRM signal can be issued in parallel both from the overreaching and underreaching functions The CS_PRM signal from the overreaching function must not be prolonged while the CS_PRM signal from the underreaching function m...

Page 1262: ... less reliable communication where the signal has to be sent through the primary fault The unblocking function uses a carrier guard signal CRG which must always be present even when no CR_PRM signal is received Due to the absence of the CRG signal during the security time the Loss of carrier time setting is used as a CR_PRM signal This also enables a permissive scheme to operate when the communica...

Page 1263: ...ual overcurrent signal for Carrier Send CR_PRM BOOLEAN 0 False Received teleprotec tion permissive from the other side CR_BLOCKING BOOLEAN 0 False Received teleprotec tion blocking from the other side CR_INTER_TR BOOLEAN 0 False Received direct trip from the other side CRG BOOLEAN 0 False Carrier guard signal received 5 11 6 2 RESCPSCH Output signals Table 1192 RESCPSCH Output signals Name Type De...

Page 1264: ...00 Minimum duration of carrier send sig nal Coordination time 0 60000 ms 1 35 Co ordination tim er for blocking scheme Table 1194 RESCPSCH Non group settings Advanced Parameter Values Range Unit Step Default Description Unblock mode 1 Off 2 Permanent 3 Time window 1 Off Unblock function mode for scheme type Loss of carrier time 0 60000 ms 1 35 Pickup security timer on loss of carrier guard signal ...

Page 1265: ...ll power system conditions In parallel feeder applications the fault current direction on the healthy feeder can change when the circuit breaker on the faulty feeder opens to clear the fault This can lead to an unwanted operation of the distance protection on the healthy parallel feeder when DSOCPSCH is used with the permissive overreach scheme The main purpose of the current reversal logic is to ...

Page 1266: ...ee voltage channels Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 5 12 5 Operation principle...

Page 1267: ...e OPR_IRV signal has a drop off delay defined with the Reversal reset time setting An internal 10 ms drop off timer enables the current reversal logic to be activated for the short duration input signals even if the Reversal reset time setting is set to zero The BLK_IRV input is used to block the activation of the OPR_IRV output The BLK_IRV input is typically connected to the forward looking zone ...

Page 1268: ...dy open Echo logic Echo logic returns the received carrier signal with the ECHO output when it receives a CR signal if no fault has been detected by the forward and reverse looking zones and the duration of CR is longer than the coordination time delay setting Wei Crd time The received carrier receive signal is also given as the CR output When the WEI logic is enabled at both feeder ends a spuriou...

Page 1269: ...nsient blocking logic can be used Assume that Relay A1 Relay A2 Relay B1 and Relay B2 are equipped with DSOCPSCH and the permissive overreach scheme is enabled A fault occurs at Feeder 1 close to bus B Relay A2 at the healthy Feeder 2 recognizes the fault in the forward direction within the overreaching zone Z2 and sends a CS signal to Relay B2 according to the POTT scheme Relay B2 does not recogn...

Page 1270: ...l condition This is used in CRWPSCH Weak end infeed logic Avoid using the WEI function at both feeder ends It can only be enabled at the weak end The weak end infeed logic should be used only in permissive schemes Setting guidelines for current reversal logic Setting Reversal reset time Set the Reversal reset time setting to the maximum reset time of the communication channel A minimum setting of ...

Page 1271: ...he protected feeder The phase to phase elements must be verified not to operate for the phase to earth faults 5 12 7 Signals 5 12 7 1 CRWPSCH Input signals Table 1199 CRWPSCH Input signals Name Type Default Description U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode BLK_IRV BOOLEAN 0 False Block of current rever sal function BLK_WEI1 BOOLEAN 0 F...

Page 1272: ... Off 3 Echo 4 Echo and Oper ate 1 Off Operating mode of WEI logic PhV level for Wei 0 10 0 90 xUn 0 01 0 70 Phase to Neutral voltage for detec tion of fault condi tion PPV level for Wei 0 10 0 90 xUn 0 01 0 70 Phase to Phase voltage for detec tion of fault condi tion Reversal time 0 60000 ms 10 20 Pickup time for cur rent reversal logic Reversal reset time 0 60000 ms 10 60 Time Delay to pre vent C...

Page 1273: ...RWPSCH Technical data Characteristic Value Operate accuracy At the frequency f fn 1 5 of the set value or 0 002 Un Operate time accuracy 1 0 of the set value or 20 ms 1MRS759142 F Protection related functions REX640 Technical Manual 1273 ...

Page 1274: ...ion of the fault current on the healthy feeder can change when the circuit breaker on the faulty feeder opens to clear the fault This can lead to an unwanted operation of the residual overcurrent protection on the healthy parallel feeder when RESCPSCH with the permissive overreach scheme is used The main purpose of the current reversal logic is to prevent such unwanted operations The permissive co...

Page 1275: ...rror if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 5 13 5 Operation principle The function can be enabled and disabled with the Operation setting The corres...

Page 1276: ...nput is used to block the activation of the OPR_IRV output The BLK_IRV input is typically connected to the start signals of the forward looking residual overcurrent function in the terminal General blocking is achieved by activating the BLOCK input Weak end infeed WEI logic The WEI logic is used to activate the residual overcurrent protection function when the fault current infeed is too low due t...

Page 1277: ...tions in the terminal except the residual overvoltage function Weak end trip logic Weak end trip logic is activated if it receives an enable signal from Level detector and ECHO output of Echo logic is activated Then a general trip signal OPR_WEI is activated The activation of the CB_OPEN input blocks the tripping The OPR_WEI output can be blocked by activating the BLOCK input 5 13 6 Application Cu...

Page 1278: ...ent reversal condition CS carrier signal sending CR carrier signal receiving Relay A2 still sends the CS signal because of the reset time delay of the forward direction residual overcurrent function of Relay A2 When Relay B2 starts to recognize the fault in the forward direction Relay B2 can malfunction and trip the breaker of the healthy feeder This problem can be solved using the reverse directi...

Page 1279: ...th the ECHO output when it receives the carrier signal CR if no fault has been detected by the forward and reverse directional measuring elements and the duration is longer than the Wei Crd time coordination time delay setting To prevent the spurious carrier receive signals from activating the WEI logic and causing unwanted communication the Wei Crd time setting can be set to 0 010 s 5 13 7 Signal...

Page 1280: ... Table 1208 RCRWPSCH Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Reversal mode 1 Off 2 On 1 Off Operating mode of Current Reversal Logic Wei mode 1 Off 3 Echo 4 Echo and Oper ate 1 Off Operating mode of WEI logic Residual voltage Val 0 05 0 70 xUn 0 01 0 25 Neutral voltage set ting for fault condi tions measurement Revers...

Page 1281: ...irectional element DPSRDIR ANSI 67P TC 5 14 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Three phase power directional ele ment DPSRDIR I1 67P TC 5 14 2 Function block Figure 726 Function block 5 14 3 Functionality The three phase power directional element function DPSRDIR is used to detect positive sequence power direction T...

Page 1282: ...pecial conditions Condition Description U3P connected to real meas urements The function can work with any two phase voltage channels connected but it is recommended to connect all three volt age channels Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the conte...

Page 1283: ...nd Reverse The sector limits are always given as positive degree values The Characteristic angle setting is also known as Relay Characteristic Angle RCA Relay Base Angle or Maximum Torque Line Low level blocking For a reliable operation signal levels should be greater than the minimum level If they are not greater than the minimum level Timer is blocked If the amplitude of the positive sequence cu...

Page 1284: ...functions 5 14 7 Signals 5 14 7 1 DPSRDIR Input signals Table 1213 DPSRDIR Input signals Name Type Default Description I3P SIGNAL Three phase currents U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode 5 14 7 2 DPSRDIR Output signals Table 1214 DPSRDIR Output signals Name Type Description RELEASE BOOLEAN Release signal if direction cri teria is sat...

Page 1285: ...ion Operation 1 on 5 off 1 on Operation Off On Table 1217 DPSRDIR Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time Min operate current 0 01 1 00 xIn 0 01 0 10 Minimum operating current Min operate volt age 0 01 1 00 xUn 0 01 0 30 Minimum operating voltage 5 14 9 DPSRDIR Monitored data Table 1218 DPSRDIR Monitored dat...

Page 1286: ... a predefined direction either in forward or reverse direction DNZSRDIR gives a release signal after a definite time delay In residual voltage selection if the angle difference between residual voltage and residual current is in a predefined direction either in forward or reverse direction DNZSRDIR gives release signal after a definite time delay This function contains a blocking functionality whi...

Page 1287: ...nnels URES calculated The function requires that all three voltage channels are con nected to calculate residual voltage Setting VT connection must be Wye in that particular UTVTR Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and a...

Page 1288: ...angle difference is within the operating sector selected by Direction mode setting the Enable signal is sent to Timer The value of Characteristic angle should be chosen in such way that all the faults in the operating direction are seen in the operating zone and all the faults in the opposite direction are seen in the backward zone The operating sector is defined by the settings Max forward angle ...

Page 1289: ...al current to the residual voltage Using the residual voltage as reference the residual current angle is compared to the Characteristic angle setting If the angle difference is within the operating sector selected by the Directional mode setting the Enable signal is sent to Timer The polarizing quantity residual voltage is inverted because of switched voltage measurement cables the correction can ...

Page 1290: ... compensated network Characteristic angle is set to 0 and 60 for solidly grounded systems In general Characteristic angle is selected so that it matches close to the expected fault angle value which results in maximum sensitivity Characteristic angle can be set anywhere between 179 to 180 The figures show examples of the operating area with RCA set to 60 and 90 respectively U0 polarizing quantity ...

Page 1291: ...grounding so that in an isolated network Characteristic angle is 90 and in a compensated network 0 In addition Characteristic angle can be changed via the control signal RCA_CTL in which case the alternatives are 90 and 0 The operation of the RCA_CTL input depends on the Characteristic angle setting The Peterson coil or the grounding resistor may be temporarily out of operation To keep the protect...

Page 1292: ...is according to DT When Timer has reached the value of Release delay time the RELEASE output is activated If a drop off situation happens that is if the operating current moves out of the operating sector or signal amplitudes drop below the minimum levels before Release delay time is exceeded the Timer reset state is activated If the drop off continues for more than Reset delay time Timer is deact...

Page 1293: ...n directional 2 Forward 3 Reverse 2 Forward Directional mode Characteristic an gle 179 180 deg 1 60 Characteristic an gle Max forward angle 0 180 deg 1 88 Maximum phase angle in forward di rection Min forward angle 0 180 deg 1 88 Minimum phase an gle in forward di rection Max reverse angle 0 180 deg 1 88 Maximum phase angle in reverse di rection Min reverse angle 0 180 deg 1 88 Minimum phase an gl...

Page 1294: ...9 DNZSRDIR Monitored data Table 1228 DNZSRDIR Monitored data Name Type Values Range Unit Description ANGLE_RCA FLOAT32 180 00 180 00 deg Angle between operat ing angle and charac teristic angle DNZSRDIR Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 5 16 Load blinder LBRDOB ANSI 21LB 5 16 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE iden...

Page 1295: ... configuration Table 1230 Special conditions Condition Description U3P connected real meas urements The function can work with any two voltage channels connec ted but it is recommended to connect all three voltage chan nels Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings check the conten...

Page 1296: ...primary ohms and angle Z1_ANGLE degrees are available in monitored data view The calculated impedance is converted to primary ohms as the operating characteristics are defined with settings in primary ohms Load impedance zone check The forward and reverse load blinder sectors are defined separately The load blinder forward area or load out region or load exporting is limited with the Max impedance...

Page 1297: ...nce impedance stays in the range limited with the Max impedance angle and Min impedance angle on reverse area the function output LB_REVERSE is activated In case Directional mode is set to Non directional operation is allowed both directions according to conditions described above Activation of the BLOCK input deactivates the function outputs 5 16 6 Application Load blinder or load encroachment fu...

Page 1298: ...d value 0 8 The resistive boundary Resistive reach Rv can be obtained in the same way as Resistive reach Fw but replace the maximum exporting active power Pexpmax and the corresponding voltage Uexpmin with the maximum importing active power Pimpmax and the corresponding voltage Uimpmin The Max impedance angle and Min impedance angle are symmetric in forward and reverse direction these values are r...

Page 1299: ...gs Table 1233 LBRDOB Group settings Basic Parameter Values Range Unit Step Default Description Resistive reach Fw 1 00 6000 00 ohm 0 01 150 00 Resistive forward reach for load dis crimination Resistive reach Rv 1 00 6000 00 ohm 0 01 150 00 Resistive reverse reach for load dis crimination Max impedance an gle 5 85 deg 1 25 Maximum angle for load area Min impedance an gle 85 5 deg 1 25 Minimum angle...

Page 1300: ... 0 00 99999 00 ohm Positive sequence im pedance amplitude Z1_ANGLE FLOAT32 180 00 180 00 deg Positive sequence im pedance phase angle LBRDOB Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 5 16 10 Technical data Table 1237 LBRDOB Technical Data Characteristic Value Operation accuracy Depending on the frequency of the current measured fn Current 1 5 of the set value or 0 002 In Voltage 1 5 o...

Page 1301: ...Reset ratio Typically 0 96 Operation time 1 2 Typically 30 ms Reset time Typically 25 ms 1 fn 50Hz results based on statistical distribution of 1000 measurements 2 Includes the delay of the signal output contact 1MRS759142 F Protection related functions REX640 Technical Manual 1301 ...

Page 1302: ...a circuit is reported to the corresponding function block in the relay configuration The function starts and operates when TCSSCBR detects a trip circuit failure The operating time characteristic for the function is DT The function operates after a predefined operating time and resets when the fault disappears The function contains a blocking functionality Blocking deactivates the ALARM output and...

Page 1303: ...circuit of the circuit breaker The function can supervise both open and closed coil circuits This supervision is necessary to find out the vitality of the control circuits continuously Figure 739 shows an application of the trip circuit supervision function use Example of both mechanical on the left and static on the right outputs TCS connections are shown The mechanical outputs PODPx are used in ...

Page 1304: ...TCS sees the situation as a faulty circuit One way to avoid TCS operation in this situation is to block the supervision function whenever the circuit breaker is open It is also recommended to block the supervision function when the trip output is active Otherwise TCS issues an alarm if the trip remains active over the set TCS Operate delay time Figure 740 shows a double pole connection of the trip...

Page 1305: ...n Trip circuit supervision and other trip contacts It is typical that the trip circuit contains more than one trip contact in parallel for example in transformer feeders where the trip of a Buchholz relay is connected in parallel with the feeder terminal and other relays involved The supervising current cannot detect if one or all the other contacts connected in parallel are not connected properly...

Page 1306: ...llel trip contacts and trip circuit supervision In case of parallel trip contacts the recommended way to do the wiring is that the TCS test current flows through all wires and joints Supervision functions 1MRS759142 F 1306 REX640 Technical Manual ...

Page 1307: ...s a sum of all TCS currents This must be taken into consideration when determining the resistance of R ext Setting the TCS function in a protection relay not in use does not typically affect the supervising current injection Trip circuit supervision with auxiliary relays Many retrofit projects are carried out partially that is the old electromechanical relays are replaced with new ones but the cir...

Page 1308: ... circuit UD Voltage drop over internal 3 mA current drain about 6 5 V I c Measuring current through the trip circuit appr 1 5 mA 0 99 1 72 mA R ext External shunt resistance R s Trip coil resistance If the external shunt resistance is used it has to be calculated not to interfere with the functionality of the supervision or the trip coil Too high a resistance causes too high a voltage drop jeopard...

Page 1309: ... the breaking capacity given in the technical manual of the protection relay Figure 743 shows incorrect usage of a TCS circuit when only one of the contacts is used Relay Rext Rext Rint Rint TCS TCS Relay Rext Rext Rint Rint TCS TCS Trip coil CB operating mechanism CB operating mechanism Trip coil Figure 743 Incorrect connection of trip circuit supervision 6 1 6 Signals 6 1 6 1 TCSSCBR Input signa...

Page 1310: ...y time 20 60000 ms 1 1000 Reset delay time 6 1 8 TCSSCBR Monitored data Table 1243 TCSSCBR Monitored data Name Type Values Range Unit Description TCSSCBR Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 6 2 Current circuit supervision CCSPVC ANSI CCM 6 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Current circuit super...

Page 1311: ...Three phase currents IRES Residual current measured See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 1245 Special conditions Condition Description IRES measured In case IRES needs to be derived the function requires that all CT cores except for the one used for phase current me...

Page 1312: ...with the Start value setting When the highest phase current is less than 1 0 In the differential current limit is defined with Start value When the highest phase current is more than 1 0 In the differential current limit is calculated with the equation MAX I A I B I C Start value _ _ _ Equation 315 The differential current is limited to 1 0 In Figure 746 CCSPVC operating characteristics When the d...

Page 1313: ...elay of three seconds The function resets when the differential current is below the start value and the highest phase current is more than 5 percent of the nominal current 0 05 In If the current falls to zero when the FAIL or ALARM outputs are active the deactivation of these outputs is prevented The activation of the BLOCK input deactivates the ALARM output 6 2 6 Application Open or short circui...

Page 1314: ...even if there was nothing wrong with the measurement circuit Reference current measured with core balanced current transformer CCSPVC compares the sum of phase currents to the current measured with the core balanced CT Figure 747 Connection diagram for reference current measurement with core balanced current transformer Current measurement with two independent three phase sets of CT cores Figure 7...

Page 1315: ...When using the measurement core for reference current measurement it should be noted that the saturation level of the measurement core is much lower than with the protection core This should be taken into account when setting the current circuit supervision function 1MRS759142 F Supervision functions REX640 Technical Manual 1315 ...

Page 1316: ...rect connection The currents must be measured with two independent cores that is the phase currents must be measured with a different core than the reference current A connection diagram shows an example of a case where the phase currents and the reference currents are measured from the same core Supervision functions 1MRS759142 F 1316 REX640 Technical Manual ...

Page 1317: ...ype Default Description I3P SIGNAL Three phase currents IRES SIGNAL Residual current BLOCK BOOLEAN 0 False Block signal for all bi nary outputs 6 2 7 2 CCSPVC Output signals Table 1247 CCSPVC Output signals Name Type Description FAIL BOOLEAN Fail output ALARM BOOLEAN Alarm output 1MRS759142 F Supervision functions REX640 Technical Manual 1317 ...

Page 1318: ...phase current 6 2 9 CCSPVC Monitored data Table 1250 CCSPVC Monitored data Name Type Values Range Unit Description IDIFF FLOAT32 0 00 40 00 xIn Differential current CCSPVC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 6 2 10 Technical data Table 1251 CCSPVC Technical data Characteristic Value Operate time including the delay of the out put contact 30 ms 6 2 11 Technical revision history T...

Page 1319: ...with the high impedance differential protection for detecting the broken CT secondary wires The differential current is taken as an input for the protection relay During normal CT condition the value of the differential current is zero However when the CT is broken the secondary differential current starts flowing and it is used for generating alarms To avoid maloperation HZCCxSPVC should have a s...

Page 1320: ...of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 6 3 5 Operation principle The function can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The operation of HZCCxSPVC can be described with a module diagram All the modules in the diagram are ...

Page 1321: ... reset timer is activated If the reset timer reaches the value set by Reset delay time the alarm timer resets The activation of the BLOCK signal resets the Timer and deactivates the ALARM output Lockout logic HZCCxSPVC is provided with the possibility to activate a lockout for the ALARM output depending on the Alarm output mode setting In the Lockout mode the ALARM must be reset manually from the ...

Page 1322: ...IxPDIF and it operates with a higher time delay A typical example of the HZCCxSPVC Start value setting is 0 1 pu with an Alarm delay time of 3 s or more As the current setting of HZCCxSPVC is more sensitive than the actual differential stage it can start internally under the through fault conditions however a sufficient time delay prevents false alarm If the bus wire is broken differential current...

Page 1323: ... arrangement does not prevent unwanted operation of HIxPDIF if the start setting is below the rated load For example if the start setting for HIxPDIF in the example is set as 0 8 pu HIxPDIF operate before HZCCxSPVC 6 3 8 Signals 6 3 8 1 HZCCASPVC Input signals Table 1254 HZCCASPVC Input signals Name Type Default Description I3P SIGNAL Three phase currents BLOCK BOOLEAN 0 False Block signal for act...

Page 1324: ...rameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Start value 1 0 100 0 In 0 1 10 0 Start value per centage of the nominal current Alarm delay time 100 300000 ms 10 3000 Alarm delay time Alarm output mode 1 Non latched 3 Lockout 3 Lockout Select the opera tion mode for alarm output Table 1261 HZCCASPVC Non group settings Advanced Parameter Values Range U...

Page 1325: ...CCCSPVC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Start value 1 0 100 0 In 0 1 10 0 Start value per centage of the nominal current Alarm delay time 100 300000 ms 10 3000 Alarm delay time Alarm output mode 1 Non latched 3 Lockout 3 Lockout Select the opera tion mode for alarm output Table 1265 HZCCCSPVC Non group setting...

Page 1326: ...ription HZCCCSPVC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 6 3 11 Technical data Table 1269 HZCCxSPVC Technical data Characteristic Value Operation accuracy Depending on the frequency of the current measured fn 2 Hz 1 5 of the set value or 0 002 In Reset time 40 ms Reset ratio Typically 0 96 Retardation time 35 ms Operate time accuracy in definite time mode 1 0 of the set value or 20...

Page 1327: ...the function issues a warning and the line differential functions are automatically internally blocked PCSITPC reacts fast for the protection communication interferences The blocking takes place at the latest when a communication interruption lasting for two fundamental network periods is detected When a severe and long lasting interference or total interruption in the protection communication cha...

Page 1328: ...output is kept active Communication interference detector The communication interference detector continuously measures and observes the sample latency of the protection telegrams This value is also available as monitored data The function provides three output signals of which only the corresponding one is active at a time depending on if the protection communication supervision is in OK WARNING ...

Page 1329: ...racy of 0 1 ms in a 50 Hz system gives a maximum amplitude error of approximately around 3 percent An inaccuracy of 1 ms gives a maximum amplitude error of approximately 31 percent The corresponding figures for a 60 Hz system are 4 and 38 percent respectively In the protection relay the time coordination is done with an echo method The protection relays create their own time reference between each...

Page 1330: ...tection communication alarm COMM BOOLEAN Communication detected ac tive when data is received 6 4 7 PCSITPC Settings Table 1271 PCSITPC Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 100 300000 ms 10 1000 Reset delay time from alarm and warning into ok state Alarm count 0 99999 1 0 Set new alarm count value Warning count 0 99999 1 0 Set new warnin...

Page 1331: ... supervision SEQSPVC FUSEF VCM 60 6 5 2 Function block Figure 757 Function block 6 5 3 Functionality The fuse failure supervision function SEQSPVC is used to block the voltage measuring functions when failure occurs in the secondary circuits between the voltage transformer or combi sensor or voltage sensor and protection relay to avoid misoperations of the voltage protection functions SEQSPVC has ...

Page 1332: ...nded to connect all three voltage channels Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 6 5...

Page 1333: ... makes a phase specific comparison between each voltage input and the Seal in voltage setting If the input voltage is lower than the setting the corresponding phase is reported to the decision logic module Current and voltage delta criterion The delta function can be activated by setting the Change rate enable parameter to True Once the function is activated it operates in parallel with the negati...

Page 1334: ...current for the same phase The measured phase current is used to reduce the risk of a false fuse failure detection If the current on the protected line is low a voltage drop in the system not caused by the fuse failure is not followed by a current change and a false fuse failure can occur To prevent this the minimum phase current criterion is checked The fuse failure detection is active until the ...

Page 1335: ... C auxiliary contact of the miniature circuit breaker protecting the VT secondary circuit The MINCB_OPEN sig nal sets the FUSEF_U output signal to block all the voltage related functions when MCB is in the open state The DISCON_OPEN input signal is supposed to be connected through a protection relay binary input to the N C auxiliary contact of the line disconnector The DISCON_OPEN signal sets the ...

Page 1336: ...hase fuse failures However at least one of the three circuits from the voltage transformers must be intact The supporting delta based function can also detect a fuse failure due to three phase interruptions In the negative sequence component based part of the function a fuse failure is detected by comparing the calculated value of the negative sequence component voltage to the negative sequence co...

Page 1337: ...it Step Default Description Neg Seq current Lev 0 03 0 20 xIn 0 01 0 03 Operate level of neg seq undercur rent element Neg Seq voltage Lev 0 03 0 20 xUn 0 01 0 10 Operate level of neg seq overvolt age element Current change rate 0 01 0 50 xIn 0 01 0 15 Operate level of change in phase current Voltage change rate 0 25 0 90 xUn 0 01 0 40 Operate level of change in phase voltage Change rate enable 0 ...

Page 1338: ...est blocked 5 off Status 6 5 10 Technical data Table 1281 SEQSPVC Technical data Characteristic Value Operate time 1 NPS function UFault 1 1 set Neg Seq voltage Lev 33 ms UFault 5 0 set Neg Seq voltage Lev 18 ms Delta function ΔU 1 1 set Voltage change rate 30 ms ΔU 2 0 set Voltage change rate 24 ms 1 Includes the delay of the signal output contact fn 50 Hz fault voltage with nominal frequency inj...

Page 1339: ...eration time exceeds the set limits It utilizes a binary input to indicate the active operation condition The accumulated operation time is one of the parameters for scheduling a service on the equipment like motors It indicates the use of the machine and hence the mechanical wear and tear Generally the equipment manufacturers provide a maintenance schedule based on the number of hours of service ...

Page 1340: ...ime mode is set to Timed Warn Alm the WARNING and ALARM outputs are activated at the time of day set using Operating time hour The Operating time hour setting is used to set the hour of day in Coordinated Universal Time UTC The setting has to be adjusted according to the local time and local daylight saving time The function contains a blocking functionality Activation of the BLOCK input blocks bo...

Page 1341: ... 6 7 MDSOPT Settings Table 1284 MDSOPT Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Warning value 0 299999 h 1 8000 Warning value for operation time su pervision Alarm value 0 299999 h 1 10000 Alarm value for op eration time super vision Table 1285 MDSOPT Non group settings Advanced Parameter Values Range Unit Step Default...

Page 1342: ... 6 6 9 Technical data Table 1287 MDSOPT Technical data Description Value Motor runtime measurement accuracy 1 0 5 6 7 Motor start counter MSCPMRI ANSI 66 6 7 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Motor start counter MSCPMRI n 66 6 7 2 Function block Figure 762 Function block 1 Of the reading for a stand alone relay wit...

Page 1343: ...T is available in the Monitored data view On the rising edge of MOT_RUN the module increments the cold start counter If the thermal content available at the TEMP_RL input is above the set Warm start level when the rising edge of the MOT_RUN input is received both cold and warm start counter values are incremented If Operation of the thermal overload protection for motors function MPTTR is set as O...

Page 1344: ...ounter exceeds the set Max Num cold start or Max Num warm start respectively When the BLK_RESTART output is active T_RST_ENA shows the possible time for the next restart The value of T_RST_ENA is calculated as the time left for both counters to decrease below their maximum number of starts Activation of the BLOCK input blocks both OPERATE and BLK_RESTART outputs 6 7 5 Application Repeated motor st...

Page 1345: ...escription OPERATE BOOLEAN Operate signal BLK_RESTART BOOLEAN Restart inhibited 6 7 7 MSCPMRI Settings Table 1290 MSCPMRI Group settings Basic Parameter Values Range Unit Step Default Description Warm start level 20 0 100 0 0 1 35 0 Thermal threshold to define a warm start Max Num cold start 1 10 1 2 Maximum number of cold start al lowed Max Num warm start 1 10 1 1 Maximum number of warm start al ...

Page 1346: ...led in minutes MSCPMRI Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 6 8 Three phase remanent undervoltage supervision MSVPR ANSI 27R 6 8 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Three phase remanent undervolt age supervision MSVPR 3U R 27R 6 8 2 Function block Figure 764 Function block 6 8 3 Functionality The th...

Page 1347: ...ration Table 1295 Special conditions Condition Description U3P connected to real measurements The function can work with one voltage chan nel connected when Phase supervision is set to A or AB B or BC or C or CA The function requires that all three voltage channels are connected if Phase supervision is set to A B C or AB BC CA Improper analog channel configuration causes a validation error if the ...

Page 1348: ...s is com pared against the Start value setting If the number of phases where the voltage is below the setting matches the Num of phases setting Level detector enables the Timer module Timer Once activated Timer runs until the value of Operate delay time has elapsed The time characteristic is according to DT When the operation timer has reached the value of Operate delay time the U_LOW output is ac...

Page 1349: ...hen the backup power can be safely connected This application example describes the re energization process MSVPR is used to supervise the Bus1 remanent voltage Control logic is used to detect the loss of primary power source and initiate the transfer to backup power Normally bus tie breaker CB5 is open and motor voltage power is supplied by incoming Feeder1 see Figure 766 M Incoming Feeder1 prima...

Page 1350: ... voltage is very low The remanent voltage setting is typically set to 20 30 percent of the rated voltage 6 8 7 Signals 6 8 7 1 MSVPR Input signals Table 1297 MSVPR Input signals Name Type Default Description U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode 6 8 7 2 MSVPR Output signals Table 1298 MSVPR Output signals Name Type Description U_LOW BO...

Page 1351: ...tored voltage phase Table 1300 MSVPR Non group settings Advanced Parameter Values Range Unit Step Default Description Reset delay time 0 60000 ms 1 20 Reset delay time 6 8 9 MSVPR Monitored data Table 1301 MSVPR Monitored data Name Type Values Range Unit Description U_AMPL_A FLOAT32 0 00 5 00 xUn Remanent voltage of phase A U_AMPL_B FLOAT32 0 00 5 00 xUn Remanent voltage of phase B U_AMPL_C FLOAT3...

Page 1352: ...E C37 2 device number Current circuit supervision for trans formers CTSRCTF MCS 3I I2 CCM 3I I2 6 9 2 Function block Figure 768 Function block 6 9 3 Functionality The current circuit supervision for transformers function CTSRCTF is used for monitoring the current transformer secondary circuit where a separate reference current transformer input for comparison is not available or where a separate v...

Page 1353: ...POFF See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the pr...

Page 1354: ...ure detection This module detects the CT secondary failure in any sets of current transformers The module continuously scans the value of all the three phase currents in all groups of current transformers to detect any sudden drop in the current value to zero The detection of a zero current should not be the only criterion for considering a fault in the current transformer secondary Two other crit...

Page 1355: ...ctivated immediately Magnitude of any phase current for any group of current transformers exceeds the Max operate current setting The magnitude of phase current is calculated from the peak to peak value Magnitude of the negative sequence current I2 on the healthy set of current transformer exceeds the Max Nq Seq current setting The INT_BLKD output is activated when FAIL is deactivated if any of th...

Page 1356: ...his change in the negative sequence current on the healthy sides that is other than where a zero current has been detected blocks the function In case of a lightly loaded transformer up to 30 the change in the negative sequence current may be very negligible However a phase discontinuity results in a change in the phase angle difference between two healthy phases in the set of CTs where a zero cur...

Page 1357: ...TGRP3 BOOLEAN CT secondary failure group 3 ALARM BOOLEAN Alarm 6 9 8 CTSRCTF Settings Table 1306 CTSRCTF Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Min operate current 0 01 0 50 xIn 0 01 0 02 Minimum operate current Max operate cur rent 1 00 5 00 xIn 0 01 1 30 Maximum operate current Max Ng Seq current 0 01 1 00 xIn 0 01...

Page 1358: ...Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 6 9 10 Technical data Table 1308 CTSRCTF Technical data Characteristic Value Operate time including the delay of the out put contact 30 ms Supervision functions 1MRS759142 F 1358 REX640 Technical Manual ...

Page 1359: ...BR is used to monitor different parameters of the circuit breaker The breaker requires maintenance when the number of operations has reached a predefined value The energy is calculated from the measured input currents as a sum of I yt values Alarms are generated when the calculated values exceed the threshold settings The function contains a blocking functionality which can be used to block the fu...

Page 1360: ...document The configuration can be written to the protection relay once the mismatch is corrected 7 1 5 Operation principle The circuit breaker condition monitoring function includes different metering and monitoring sub functions The functions can be enabled and disabled with the Operation setting The corresponding parameter values are On and Off The operation counters are cleared when Operation i...

Page 1361: ...ng charge indication Gas pressure supervisio n RST_TRV_T I3P I_A I_B OPEN_CB_EXE CLOSE_CB_EXE I_C RST_SPR_T Figure 771 Functional module diagram 7 1 5 1 Circuit breaker status The Circuit breaker status sub function monitors the position of the circuit breaker that is whether the breaker is in open closed or invalid position The operation of the breaker status monitoring can be described by using ...

Page 1362: ...The status of the breaker is indicated by the binary outputs OPENPOS INVALIDPOS and CLOSEPOS for open invalid and closed position respectively 7 1 5 2 Circuit breaker operation monitoring The purpose of the circuit breaker operation monitoring subfunction is to indicate if the circuit breaker has not been operated for a long time The operation of the circuit breaker operation monitoring can be des...

Page 1363: ...ker contact travel time Traveling time calculator The travel time can be calculated using two different methods based on the setting Travel time Clc mode When the setting Travel time Clc mode is From Pos to Pos the contact travel time of the breaker is calculated from the time between auxiliary contacts state change The opening travel time is measured between the opening of the POSCLOSE auxiliary ...

Page 1364: ...tween the start of the main contact opening and the OPEN_CB_EXE command Similarly there is a time gap t 2 between the time when the POSOPEN auxiliary contact opens and the main contact is completely open Therefore to incorporate the times t 1 and t 2 a correction factor needs to be added with t open to get the actual opening time This factor is added with the Opening time Cor t 2 t 1 setting The c...

Page 1365: ...ols via communications The old circuit breaker operation counter value can be taken into use by writing the value to the Counter initial Val parameter and by setting the parameter CB wear values in the clear menu from WHMI or LHMI Alarm limit check The OPR_ALM operation alarm is generated when the number of operations exceeds the value set with the Alarm Op number threshold setting However if the ...

Page 1366: ...auxiliary contact has opened and when the delay is equal to the value set with the Difference Cor time setting When the setting is negative the calculation starts in advance by the correction time before the auxiliary contact opens The accumulated energy outputs IPOW_A _B _C are available in the monitored data view on the LHMI or through tools via communications The values can be reset by setting ...

Page 1367: ...alculates the remaining life of the circuit breaker The Op number rated and Op number fault parameters set the number of operations the breaker can perform at the rated current and at the rated fault current If the tripping current is lower than the rated operating current set with the Rated Op current setting the remaining operation of the breaker reduces by one operation If the tripping current ...

Page 1368: ...tes the spring charging time The operation of the subfunction can be described with a module diagram All the modules in the diagram are explained in the next sections Figure 781 Functional module diagram for circuit breaker spring charged indication and alarm Spring charge time measurement Two binary inputs SPR_CHR_ST and SPR_CHR indicate spring charging started and spring charged respectively The...

Page 1369: ...breaker status monitors the position of the circuit breaker that is whether the breaker is in an open closed or intermediate position Circuit breaker operation monitoring The purpose of the circuit breaker operation monitoring is to indicate that the circuit breaker has not been operated for a long time The function calculates the number of days the circuit breaker has remained inactive that is ha...

Page 1370: ...e is a possibility to set an initial value for the counter which can be used to initialize this functionality after a period of operation or in case of refurbished primary equipment Accumulation of I y t Accumulation of I yt calculates the accumulated energy ΣI yt where the factor y is known as the current exponent The factor y depends on the type of the circuit breaker For oil circuit breakers th...

Page 1371: ...efore after one operation of 10 kA the remaining life of the circuit breaker is 15 000 500 14 500 at the rated operating current Spring charged indication For normal operation of the circuit breaker the circuit breaker spring should be charged within a specified time Therefore detecting long spring charging time indicates that it is time for the circuit breaker maintenance The last value of the sp...

Page 1372: ...close com mand to coil PRES_ALM_IN BOOLEAN 0 False Binary pressure alarm input PRES_LO_IN BOOLEAN 0 False Binary pressure input for lockout indication SPR_CHR_ST BOOLEAN 0 False CB spring charging started input SPR_CHR BOOLEAN 0 False CB spring charged in put RST_IPOW BOOLEAN 0 False Reset accumulation energy RST_CB_WEAR BOOLEAN 0 False Reset input for CB re maining life and oper ation counter RST...

Page 1373: ...arm PRES_ALM BOOLEAN Pressure below alarm level PRES_LO BOOLEAN Pressure below lockout level OPENPOS BOOLEAN CB is in open position INVALIDPOS BOOLEAN CB is in invalid position not positively open or closed CLOSEPOS BOOLEAN CB is in closed position 7 1 8 SSCBR Settings Table 1312 SSCBR Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation...

Page 1374: ...1 1000 Number of opera tions possible at rated fault current Inactive Alm days 0 9999 1 2000 Alarm limit value of the inactive days counter Travel time Clc mode 1 From Cmd to Pos 2 From Pos to Pos 2 From Pos to Pos Travel time calcu lation mode selec tion Table 1313 SSCBR Non group settings Advanced Parameter Values Range Unit Step Default Description Opening time Cor 100 100 ms 1 10 Correction fa...

Page 1375: ... CB Remaining life phase B CB_LIFE_C INT32 99999 99999 CB Remaining life phase C IPOW_A FLOAT32 0 000 30000 000 Accumulated currents power Iyt phase A IPOW_B FLOAT32 0 000 30000 000 Accumulated currents power Iyt phase B IPOW_C FLOAT32 0 000 30000 000 Accumulated currents power Iyt phase C SSCBR Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 7 1 10 Technical data Table 1315 SSCBR Technical...

Page 1376: ...onnector supervision ESDCSSWI is used for monitoring switch status inactivity contact travel time and operation counter Function can be used for condition monitoring and as indicator for maintenance need 7 2 4 Operation principle The Operation setting is used to enable or disable the function When selected On the function is enabled and respectively Off means function is disabled The operation of ...

Page 1377: ...ALSE and the POSCLOSE input is TRUE The INVALIDPOS output is activated when both auxiliary contacts have the same value that is both are in the same logical level 7 2 4 2 Inactivity monitoring The purpose of the inactivity monitoring is to indicate if the earthing switch or disconnector has not been operated for a long time This module calculates the number of days the earthing switch or disconnec...

Page 1378: ... from WHMI or LHMI The OPR_ALM operation warning is generated when the number of operations exceeds the value set with the Alarm Op number threshold setting However if the number of operations increases further and exceeds the limit value set with the Lockout Op number setting the OPR_LO output is activated The binary outputs OPR_ALM and OPR_LO are deactivated when the BLOCK input is activated 7 2...

Page 1379: ...OSOPEN auxiliary contact The closing travel time is measured between rising edge of the CLOSE_EXE command and POSCLOSE auxiliary contact Main contact POSCLOSE 0 1 0 1 POSOPEN tclose topen T_TRV_OP topen T_TRV_CL tclose open close close OPEN_EXE CLOSE_EXE Figure 787 Travel time calculation when Travel time Clc mode is From Cmd to Pos The last measured opening travel time T_TRV_OP and the closing tr...

Page 1380: ...to continued exposure of varying weather conditions Supervision of following parameters helps understanding the mechanical condition and need for maintenance Increasing contact travel time might be indication e g of mechanical wear or lubrication problem Certain maintenance actions are dependent on operation counter value Mechanism may be stuck if switch is in same position long period of time Ina...

Page 1381: ...ion 7 2 7 ESDCSSWI Settings Table 1318 ESDCSSWI Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Open alarm time 40 30000 ms 10 15000 Alarm level setting for open travel time in ms Close alarm time 40 30000 ms 10 15000 Alarm level setting for close travel time in ms Alarm Op number 0 99999 1 200 Alarm limit for number of opera...

Page 1382: ...60000 ms Travel time of the switch during closing operation T_TRV_MAX_OP FLOAT32 0 60000 ms Maximum travel time during opening opera tion T_TRV_MAX_CL FLOAT32 0 60000 ms Maximum travel time during closing opera tion NO_OPR INT32 0 99999 Number of switch oper ation cycle INA_DAYS INT32 0 9999 The number of days switch has been inac tive ESDCSSWI Enum 1 on 2 blocked 3 test 4 test blocked 5 off Statu...

Page 1383: ...ormer from three phase currents and RTD inputs for top oil temperature and ambient temperature The hot spot temperature and the momentary ageing rate are calculated based on the IEC 60076 7 or the IEEE C57 91 2011 standard depending upon a user defined setting The total ageing and loss of transformer insulation life is calculated in years The function generates WARNING and ALARM signals if the cal...

Page 1384: ...LM_AGE_RATE RST_AVGAGING TOPOIL_TEMP HOTSPOT_TEMP Figure 789 Functional module diagram 7 3 5 1 Load factor calculation and parameter selection The transformer top oil and hot spot temperatures are dependent on the load factor the winding conductor properties and the cooling oil properties of the transformer This module calculates the load factor based on the measured phase currents and selects the...

Page 1385: ...lected as per the IEC 60076 7 guidelines based on Table 1323 Table 1323 Constants based IEC guidelines Distribution Transformers Medium and Large power transformers Cooling mode ONAN ONAN ONAF OFAF ODAF Oil Exponent x 0 8 0 8 0 8 1 0 1 0 Winding Exponent y 1 6 1 3 1 3 1 3 2 0 Constant K11 k11 1 00 0 50 0 50 1 00 1 00 Constant K21 k21 1 00 2 00 2 00 1 30 1 00 Constant K22 k22 2 00 2 00 2 00 1 00 1 ...

Page 1386: ...ant Շ0 and winding time constant Շw in Table 1324 are kept same as in Table 1323 For more accuracy the values of the constants can be entered manually by setting Parameter Sel method to Manual 7 3 5 2 Top oil temp calculation The function receives two sensor inputs for measuring top oil temperature and ambient temperature The top oil temperature of the tank is obtained through a sensor placed at t...

Page 1387: ...equation resulting in the following equations θ θ θ 0 0 2 1 1 K R R x or a Equation 323 The top oil temperature at the nth time step is calculated as shown below TOPOIL TEMP D n n _ θ θ 0 1 0 Equation 324 The measured calculated top oil temperature TOPOIL_TEMP is available in the Monitored data view If the top oil temperature sensor is valid the TOPOIL_TEMP output is equal to the measured top oil ...

Page 1388: ...petest I y Equation 328 Where Irated Rated current of the transformer Hotspot Tmp rise Hot spot temperature rise over ambient at rated load Top oil Tmp rise Top oil temperature rise over ambient at rated load Current type test Current applied in type testing to reach rated hot spot temperature At each time step the nth value of DΔθh1 n and DΔθh2 n are calculated from the n 1 value the solutions of...

Page 1389: ... reserve in percentage to reach the alarm condition LD_RSV_ALM_PCT and to reach the warning condition LD_RSV_WRN_PCT These outputs can be obtained from the Monitored data view If the warning condition is reached the LD_RSV_WRN_PCT output is forced to zero and if the alarm condition is reached LD_RSV_ALM_PCT is forced to zero The load reserve outputs are only indicative and are calculated based on ...

Page 1390: ...The setting Avg Age rate period can be set to DAY WEEK MONTH or YEAR For example if the Avg Age rate period is set to MONTH the output AVG_AGE_RATE is updated every day with the average ageing rate since the day the calculation started Once a month is completed the AVG_AGE_RATE is calculated over the previous 30 days That is after the 31st day the average ageing rate is calculated from day 2 to da...

Page 1391: ... AVG_AGE_RATE is restarted If the Avg Age rate period is set to YEAR the output AVG_AGE_RATE is refreshed once in 30 days starting from the time the relay is installed or since the last activation of binary input RST_AVGAGING The activation of the BLOCK input deactivates the ALM_AGE_RATE output 7 3 6 Application The insulation used in transformer windings is paper oil insulation that can degrade o...

Page 1392: ...ated using the empirical formulae The hot spot temperature calculation is dependent upon the thermal properties of the winding material cooling oil and the cooling mode of the transformer The thermal model may also differ from IEC and IEEE markets though the underlying principle of temperature calculation remains the same The transformer constants are decided based on a user defined setting to sel...

Page 1393: ...ding This function does not calculate the rise in actual hot spot temperature which occurs due to oil flow blockage or malfunction of cooler groups That said the set oil and winding properties can be updated manually to indicate this change Based on the calculated hot spot temperature the function calculates the relative ageing that is the accelerated or decelerated ageing of the insulation at cur...

Page 1394: ...ng of the transformer over a defined time period For example during a planned overloading of a transformer for a period of one month In such cases it is important to know the ageing rate during that period of overload rather than the overall loss of life transformer Hence an additional output on average ageing rate over a settable average ageing period is provided in the function The function can ...

Page 1395: ...e 1327 HSARSPTR Group settings Basic Parameter Values Range Unit Step Default Description Cooling mode 1 ONAN 2 ONAF 3 OFAF 4 ODAF 1 ONAN Transformer cool ing method Alarm level 50 0 350 0 C 0 1 120 0 Alarm level for hot spot temperature Warning level 50 0 350 0 C 0 1 100 0 Warning level for hotspot tempera ture Alarm delay time 0 3600000 ms 10 10000 Time delay for hot spot temperature alarm Warni...

Page 1396: ...1 500000 0 0 1 25 0 Ratio of load losses at rated load to no load losses CT ratio correction 0 200 5 000 0 001 0 200 Current transform er ratio correction factor Oil exponent 0 10 10 00 0 01 0 10 User defined value for oil exponent Winding exponent 0 10 10 00 0 01 0 10 User defined value for winding expo nent Constant K11 0 01 10 00 0 01 1 00 User defined value of thermal model constant K11 Consta...

Page 1397: ...D_RSV_ALM_PCT FLOAT32 0 0 1000 0 Percentage load reserve for reaching alarm con dition AGEING_RATE FLOAT32 0 00 50 00 Momentary relative ageing rate LOSS_OF_LIFE FLOAT32 0 100 Loss of life in years AVG_AGE_RATE FLOAT32 0 100 Average ageing rate over set time period HSARSPTR Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 7 3 10 Technical data Table 1331 HSARSPTR technical data Characteristi...

Page 1398: ...h The function determines the self clearing fault is detected in all three phases or earth 7 4 4 Analog input configuration RCFD has two analog group inputs which must be properly configured Table 1332 Analog inputs Input Description I3P Three phase currents IRES Measured residual current See the preprocessing function blocks in this document for the possible signal sources Improper analog channel...

Page 1399: ...sts the options for monitoring and available monitored data values Table 1333 SCF monitoring options and data values Measurement channel Calculated cycle DFT current Start detection SCF indication SCF counter Phase A current I_A I_CLC_AMPL_A STR_DET_A SLFCLR_FLT_A SLFCLR_CNT_A Phase B current I_B I_CLC_AMPL_B STR_DET_B SLFCLR_FLT_B SLFCLR_CNT_B Phase C current I_C I_CLC_AMPL_C STR_DET_C SLFCLR_FLT...

Page 1400: ... and Residual current limit then the adaptive start value are set to twice the Minimum load current and Residual current limit In case fault is detected the adaptive start value will hold the last updated one minute average of phase and residual current The adaptive start values of corresponding phases or residual are displayed in monitored data ADP_ST_VAL_A ADP_ST_VAL_B ADP_ST_VAL_C and ADP_ST_VA...

Page 1401: ...0 10 40 00 xIn 0 01 0 10 Fault current threshold Maximum fault cy cle 1 20 1 5 Fault detect thresh old parameter in fundamental cycles Minimum load cur rent 0 00 1 00 xIn 0 10 0 10 Absolute minimum loading on the feeder Adaptive Str Val Ena 0 False 1 True 0 False Adaptive threshold enable Residual start value 0 10 40 00 xIn 0 01 0 50 Fault residual cur rent threshold Residual current limit 0 00 1 ...

Page 1402: ...T_A BOOLEAN 0 False 1 True Self clearing fault de tected phase A SLFCLR_FLT_B BOOLEAN 0 False 1 True Self clearing fault de tected phase B SLFCLR_FLT_C BOOLEAN 0 False 1 True Self clearing fault de tected phase C SLFCLR_FLT_N BOOLEAN 0 False 1 True Self clearing fault de tected residual ADP_ST_VAL_A FLOAT32 0 00 40 00 xIn Used adaptive start val ue phase A ADP_ST_VAL_B FLOAT32 0 00 40 00 xIn Used ...

Page 1403: ...10 ms 15 ms 20 ms 7 5 Diesel generator monitoring and protection DGMGAPC ANSI 32 40G 7 5 1 Identification Table 1340 Function identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Diesel generator monitoring and protection function DGMGAPC P U f 32 40G 1 Results based on statistical distribution of 1000 measurements 2 Measured with stat...

Page 1404: ...determination to identify the components connected in its own electrical network and exchanges relevant data with all other relays having DGMGAPC function and present in the same IEC61850 network The DGMGAPC identifies a fault in the generator by comparing its behavior to its current governor mode or with reference to other generators in the network When a fault is detected the function will signa...

Page 1405: ...e voltage chan nels Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings check the contents of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 7 5 5 Operation principle The Operation settin...

Page 1406: ...FLT_DETECTED INT_BLKD EXTERNAL_FLT GCB_OPEN TIE_B_CLOSED TIE_A_OPEN U3P GCB_TRP_FAIL TIE_TRP_FAIL Figure 796 Functional module diagram 7 5 5 1 Topology determination The Topology determination module identifies the group of busbar and generators that are electrically connected and calculates the subnetwork number for each group The maximum network configuration considered is 8 generators 8 GCBs an...

Page 1407: ...sbar to form the different subnetwork groups Each tie breaker connects two busbars and these are referred to as bus A and bus B Hence two settings are used to indicate the connection of a tie breaker to the two busbars For example If tie breaker 1 connects busbar1 and busbar2 then setting Tie 1 busbar A Num is set to Bus 1 and Tie 1 busbar B Num is set to Bus 2 If a tie breaker is not configured i...

Page 1408: ...y the function Based on this information the Topology determination module determines the different subnetwork groups Each network group is assigned a network number which is the lowest busbar number in the sub group For example in Figure 798 c the subnetwork group has busbar 5 6 7 and 8 Hence the subnetwork number of this group is 5 If an element is not electrically connected to any busbar then a...

Page 1409: ..._FLT UN_EXCT_FLT U3P Topology input from topology determination GOV_MOD_ISOC AVR_MODE_DRP FUEL_RCK_POS Fuel rack position Monitoring I_EXCITATION I3P GEN_MOD_LOC GOV_MOD_DRP Q1 Q2 Q8 Excitation current monitoring Fueling fault detection Excitation fault detection GOV_MOD_BASE FUEL_RCK_FLT I_EXCT_FLT P1 P2 P8 GOV_MOD_CDRP CDRP_F_SET BASE_P_SET ENG_LOD_UNLD OV_FUEL_FLT UN_FUEL_FLT OV_EXCT_FLT UN_EXC...

Page 1410: ...ator Num is set to 1 then P1 is considered as the local generator active power output Correlation algorithm uses different criteria based on the governor mode The governor mode information is obtained through the four binary inputs GOV_MOD_ISOC GOV_MOD_DRP GOV_MOD_CDRP and GOV_MOD_BASE The governor and AVR modes of other generators are obtained through inputs GEN1_DATA GEN8_DATA In case any genera...

Page 1411: ...the quality of the signal CDRP_F_SET is not reliable the module is disabled and INT_BLKD output is activated When input GOV_MOD_BASE is active the local active power is compared to the load set point received from PMS BASE_P_SET The BASE_P_SET input is a 0 20mA signal obtained through an RTD input If the local active power deviates from this set point by a margin greater than the set Max P Dev Crl...

Page 1412: ...in the same subnetwork are considered for com parison UN_FUEL_FLT GOV_MOD_DRP TRUE F F set point no load Frequency droop 0 01 P Max Freq deviation GOV_MOD_CDRP TRUE F F_CALC_LIMIT Max Freq deviation GOV_MOD_BASE TRUE P BASE_P_SET Max P Dev Crl Voting algorithm Voting algorithm is applied to groups of generators running in parallel Voting algorithm compares the behavior of the local generator with ...

Page 1413: ...by Voting algorithm in the event that several generators should suffer from a common mode failure Excitation fault detection This module detects problems with the generator excitation or AVR which result in excessive reactive power over excitation or insufficient reactive power under excitation production by the generator As in Fueling fault detection block the excitation faults are also detected ...

Page 1414: ...lt detection criteria Output activation Over excitation fault Uavg U set point no load Voltage droop 0 01 Q Max Volts deviation OV_EXCT_FLT Under excitation fault Uavg U set point no load Voltage droop 0 01 Q Max Volts deviation UN_EXCT_FLT Voting algorithm As in Fueling fault detection block the Voting algorithm for excitation faults is also applied when at least 3 generators including the local ...

Page 1415: ...erator reactive power output Fuel rack position monitoring This module compares the position of the engine s fuel rack obtained as input FUEL_RCK_POS to the active power P The FUEL_RCK_POS input is a 0 20mA signal obtained through an RTD input An offset linear relationship refer Figure 801 is assumed between the fuel rack position and the generator active power The droop characteristics can be par...

Page 1416: ...e setting Disable Ext Cur Mon For both the Fuel rack position monitoring and the Excitation current monitoring modules an internal delay of 100ms is assumed before activation of FUEL_RCK_FLT and I_EXCT_FLT outputs This delay is to enable the generator mechanics to respond to the changes in fuel rack position and excitation current 7 5 5 3 Control logic Once activated by either the Fuel fault detec...

Page 1417: ...is One among the network generators enter over power region OR F Min Freq limit Max Freq deviation AND P 0 0 That is local generator enters reverse power zone Table 1348 Criteria for activation of DE_EXCITE output Fault type Criteria Output Over excitation fault MIN Q1 Q8 Min reactive power OR Uavg Max voltage limit Max Volts deviation DE_EXCITE Under excitation fault Uavg Min voltage limit Max Vo...

Page 1418: ...ctivates TIE_TRP_FAIL output The information on tie A or tie B side breaker tripping failure is shared with other DGMGAPC functions in the network through output GEN_DATA to initiate tripping of tie breaker If the DGMGAPC function receives tie breaker trip failure indication from a generator which shares a tie breaker with the local generator then the module initiates tripping of that shared tie b...

Page 1419: ...twork Two algorithms are used to detect fueling and excitation faults namely Correlation and Voting algorithms The Correlation algorithm compares the generator behavior with the set operation mode of the governor If the local generator is deviating significantly then it is identified as faulty The Voting algorithm works on the assumption that generators share the load similarly Hence a generator i...

Page 1420: ...y identification enables the function to locate a particular fault in the network and trip the neighboring tie breakers of healthy generators in case a network generator is faulty and is still not tripped The application configuration needs to ensure that in case any protection functions like over speed protection or over voltage protection or if generator operates outside stability limit then a s...

Page 1421: ... of net work generator 8 Q1 FLOAT32 0 0 Reactive power of network generator 1 Q2 FLOAT32 0 0 Reactive power of network generator 2 Q3 FLOAT32 0 0 Reactive power of network generator 3 Q4 FLOAT32 0 0 Reactive power of network generator 4 Q5 FLOAT32 0 0 Reactive power of network generator 5 Q6 FLOAT32 0 0 Reactive power of network generator 6 Q7 FLOAT32 0 0 Reactive power of network generator 7 Q8 F...

Page 1422: ...block all binary outputs GCB_CLOSED BOOLEAN 0 False Local generator cir cuit breaker closed position status GCB_OPEN BOOLEAN 0 False Local generator cir cuit breaker open po sition status TIE_A_CLOSED BOOLEAN 0 False Adjacent tie breaker A closed position TIE_A_OPEN BOOLEAN 0 False Adjacent tie breaker A open position TIE_B_CLOSED BOOLEAN 0 False Adjacent tie breaker B closed position TIE_B_OPEN B...

Page 1423: ...TE BOOLEAN De excite the generator PRE_TRIP BOOLEAN Pre trip signal indicating im minent trip of generator FLT_DETECTED BOOLEAN Fault detected in the local generator OV_FUEL_FLT BOOLEAN Over fueling fault detected UN_FUEL_FLT BOOLEAN Under fueling fault detected OV_EXCT_FLT BOOLEAN Over excitation fault detected UN_EXCT_FLT BOOLEAN Under excitation fault detec ted GCB_TRP_FAIL BOOLEAN Trip command...

Page 1424: ...05 xFn 0 01 1 05 Maximum Freq lim it above which STOP_ENGINE is ac tivated Min voltage limit 0 5 1 5 xUn 0 1 0 8 Minimum voltage limit below which DE_EXCITE is acti vated Max voltage limit 0 5 1 5 xUn 0 1 1 2 Maximum voltage limit above which DE_EXCITE is acti vated Operate delay time 10 300000 ms 10 600 Operate delay time Max CB trip delay 10 300000 ms 10 600 Maximum time de lay for detection of ...

Page 1425: ...In 0 0005 0 0100 Excitation current when generator is on no load Ext current gain 0 0100 10 0000 0 0005 1 0000 Rate of change of excitation Curr from no load to full load Table 1353 DGMGAPC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Total Num of Gn 1 8 1 8 Total number of generators Total Num of tie 1 8 1 8 Total number ...

Page 1426: ...3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar number of generator 2 Gn 3 busbar Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar number of generator 3 Gn 4 busbar Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar number of generator 4 Gn 5 busbar Num 0 Not configured 1 Bus1 2 Bus2 ...

Page 1427: ... 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar number of generator 8 Tie 1 busbar A Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar A number of tie breaker 1 Tie 1 busbar B Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar B number of tie breaker 1 Tie 2 busbar A Num 0...

Page 1428: ... Not configured Busbar A number of tie breaker 3 Tie 3 busbar B Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar B number of tie breaker 3 Tie 4 busbar A Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar A number of tie breaker 4 Tie 4 busbar B Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 0 Not conf...

Page 1429: ...r B number of tie breaker 5 Tie 6 busbar A Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar A number of tie breaker 6 Tie 6 busbar B Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 7 Bus7 8 Bus8 0 Not configured Busbar B number of tie breaker 6 Tie 7 busbar A Num 0 Not configured 1 Bus1 2 Bus2 3 Bus3 4 Bus4 5 Bus5 6 Bus6 0 Not conf...

Page 1430: ...ait time signal status 0 100 ms 1 50 Wait time between Load Unload signal and GCB status Wait time status signal 0 100 ms 1 50 Wait time between GCB status and Load Unload signal 7 5 9 DGMGAPC Monitored data Table 1355 DGMGAPC Monitored data Name Type Values Range Unit Description I_MAX FLOAT32 0 00 5 00 xIn Maximum of the three phase input currents F_CALC_LIMIT FLOAT32 0 00 2 00 xFn Calculated Fr...

Page 1431: ... True Fault in network gener ator 2 FAULT_GEN3 BOOLEAN 0 False 1 True Fault in network gener ator 3 FAULT_GEN4 BOOLEAN 0 False 1 True Fault in network gener ator 4 FAULT_GEN5 BOOLEAN 0 False 1 True Fault in network gener ator 5 FAULT_GEN6 BOOLEAN 0 False 1 True Fault in network gener ator 6 FAULT_GEN7 BOOLEAN 0 False 1 True Fault in network gener ator 7 FAULT_GEN8 BOOLEAN 0 False 1 True Fault in n...

Page 1432: ...IE_CB6 INT32 0 8 Subnetwork number of tie breaker 6 SBNW_TIE_CB7 INT32 0 8 Subnetwork number of tie breaker 7 SBNW_TIE_CB8 INT32 0 8 Subnetwork number of tie breaker 8 DGMGAPC Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 7 5 10 Technical data Table 1356 Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured voltage and current fn 2 Hz Voltage 1 ...

Page 1433: ...m The sequence current measurement CSMSQI is used for monitoring and metering the phase sequence currents The sequence voltage measurement VSMSQI is used for monitoring and metering the phase sequence voltages The frequency measurement FMMXU is used for monitoring and metering the power system frequency The three phase power and energy measurement PEMMXU is used for monitoring and metering the act...

Page 1434: ...g average calculation of the measured signal over the demand time interval A new demand value is obtained once in a minute indicating the analog signal demand over the demand time interval proceeding the update time The actual rolling demand values are stored in the memory until the value is updated at the end of the next time interval The Logarithmic calculation mode uses the periodic calculation...

Page 1435: ...l In Three phase voltage measurement VMMXU 1 of nominal Un Phase to earth voltage measurement VPHMMXU 1 of nominal Un Residual current measurement RESCMMXU 1 of nominal In Residual voltage measurement RESVMMXU 1 of nominal Un Phase sequence current measurement CSMSQI 1 of the nominal In Phase sequence voltage measurement VSMSQI 1 of the nominal Un Three phase power and energy measurement PEMMXU 1 ...

Page 1436: ...t measurement CMMXU High limit A high limit Low limit A low limit High high limit A high high limit Low low limit A low low limit Three phase voltage measurement VMMXU High limit V high limit Low limit V low limit High high limit V high high limit Low low limit V low low limit Phase voltage measurement VPHMMXU High limit V high limit Low limit V low limit High high limit V high high limit Low low ...

Page 1437: ...low Lim Zro A low low Lim Phase sequence voltage measurement VSMSQI High limit Ps Seq V high limit Ng Seq V high limit Zro V high limit Low limit Ps Seq V low limit Ng Seq V low limit Zro V low limit High high limit Ps Seq V Hi high Lim Ng Seq V Hi high Lim Zro V Hi high Lim Low low limit Ps Seq V low low Lim Ng Seq V low low Lim Three phase power and energy measurement PEMMXU High limit Low limit...

Page 1438: ...ST_A I_DB_A 0 30 If I_INST_A changes to 0 40 the reporting delay is t s s 40 0 2500 1000 0 40 0 30 100 10 Table 1359 Parameters for deadband calculation Function Settings Minimum maximum Three phase current measurement CMMXU A deadband 0 04 40 Three phase voltage measurement VMMXU V deadband 0 004 4 Phase voltage measurement VMHMMXU V deadband 0 004 4 Single phase voltage measurement VAMM XU V dea...

Page 1439: ...asurement mode determines which voltage and current measurements are used It is also possible to use positive sequence components for calculating the apparent power which makes the determination of power insensitive to any asymmetry in currents or voltages Table 1360 Measured apparent power Measurement mode setting values Power calculation PhsA PhsB PhsC S U I U I U I A A B B C C Equation 339 Aron...

Page 1440: ...available set of measurements P S Re Equation 348 Q S Im Equation 349 S S P Q 2 2 Equation 350 Cos P S ϕ Equation 351 The calculated powers are available as function outputs S_INST P_INST Q_INST and the power factor angle as PF_INST Depending on the unit multiplier selected with Power unit Mult the calculated power values in the monitored data and measurement view are presented in units of kVA kW ...

Page 1441: ...e calculated power values are presented in units of kWh kVArh or in units of MWh MVArh When the energy counter reaches its defined maximum value the counter value is reset and restarted from zero Changing the value of the Energy unit Mult setting resets the accumulated energy values to the initial values that is EA_FWD_ACM to Forward Wh Initial EA_RV_ACM to Reverse Wh Initial ER_FWD_ACM to Forward...

Page 1442: ...le values The demand values are used to neglect sudden changes in the measured analog signals when monitoring long time values for the input signal The demand values are linear average values of the measured signal over a settable demand interval The demand values are calculated for the measured analog three phase current signals The limit supervision indicates if the measured signal exceeds or go...

Page 1443: ... in amperes These outputs are dedicated for Load profile recorder LDPRLRC 8 1 4 4 Analog channel configuration CMMXU has one analog group input which must be properly configured Table 1362 Analog inputs Input Description I3P Three phase currents See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if ...

Page 1444: ...FLOAT32 Phase C current instantane ous value amplitude in am peres I_DMD_A FLOAT32 Demand value of IL1 current I_DMD_B FLOAT32 Demand value of IL2 current I_DMD_C FLOAT32 Demand value of IL3 current 8 1 4 6 CMMXU Non group settings Table 1365 CMMXU Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on Operation Off On Num of phases 1 1 out of 3 Number of phas...

Page 1445: ...0 00 40 00 xIn Measured current am plitude phase B IL3 A 1 FLOAT32 0 00 40 00 xIn Measured current am plitude phase C Max demand IL1 FLOAT32 0 00 40 00 xIn Maximum demand for Phase A Max demand IL2 FLOAT32 0 00 40 00 xIn Maximum demand for Phase B Max demand IL3 FLOAT32 0 00 40 00 xIn Maximum demand for Phase C Min demand IL1 FLOAT32 0 00 40 00 xIn Minimum demand for Phase A Min demand IL2 FLOAT32...

Page 1446: ...igh high 4 low low IL1 Amplitude range I_INST_B FLOAT32 0 00 40 00 xIn IL2 Amplitude magni tude of instantaneous value I_ANGL_B FLOAT32 180 00 180 00 deg IL2 current angle I_DB_B FLOAT32 0 00 40 00 xIn IL2 Amplitude magni tude of deadband value I_DMD_B FLOAT32 0 00 40 00 xIn Demand value of IL2 current I_RANGE_B Enum 0 normal 1 high 2 low 3 high high 4 low low IL2 Amplitude range I_INST_C FLOAT32 ...

Page 1447: ...ber Three phase voltage measurement VMMXU 3U VA VB VC 8 1 5 2 Function block Figure 807 Function block 8 1 5 3 Functionality The three phase voltage measurement function VMMXU provides limit value supervision output HIGH_ALARM HIGH_WARN LOW_WARN LOW_ALARM Setting parameters On delay time and Off delay time are used for controlling the activation and the deactivation of alarm and warning outputs In...

Page 1448: ...s set to 1 out of 3 The function requires that at least two volt age channels are connected if Num of start phases is set to 2 out of 3 The function requires that all three voltage channels are connected if Num of start pha ses is set to 3 out of 3 Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain ...

Page 1449: ...mand value of U23 voltage U_DMD_CA FLOAT32 Demand value of U31 voltage U_DMD_A FLOAT32 Demand value of UL1 voltage U_DMD_B FLOAT32 Demand value of UL2 voltage U_DMD_C FLOAT32 Demand value of UL3 voltage 8 1 5 6 VMMXU Settings Table 1373 VMMXU Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Num of phases 1 1 out of 3 2 2 out o...

Page 1450: ...voltage ampli tude phase BC U31 kV 1 FLOAT32 0 00 4 00 xUn Measured phase to phase voltage ampli tude phase CA UL1 kV 1 FLOAT32 0 00 5 00 xUn Measured phase to earth voltage amplitude phase A UL2 kV 1 FLOAT32 0 00 5 00 xUn Measured phase to earth voltage amplitude phase B UL3 kV 1 FLOAT32 0 00 5 00 xUn Measured phase to earth voltage amplitude phase C BLOCK BOOLEAN 0 False 1 True Block signal for ...

Page 1451: ...g U31 angle U_DB_CA FLOAT32 0 00 4 00 xUn U31 amplitude magni tude of deadband value U_DMD_CA FLOAT32 0 00 4 00 xUn Demand value of U31 voltage U_RANGE_CA Enum 0 normal 1 high 2 low 3 high high 4 low low U31 amplitude range U_INST_A FLOAT32 0 00 5 00 xUn UL1 amplitude magni tude of instantaneous value U_ANGL_A FLOAT32 180 00 180 00 deg UL1 angle U_DMD_A FLOAT32 0 00 5 00 xUn Demand value of UL1 vo...

Page 1452: ...ue Operation accuracy Depending on the frequency of the voltage measured fn 2 Hz At voltages in range 0 01 1 15 Un 0 5 or 0 002 Un Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 RMS No suppression Measurement functions 1MRS759142 F 1452 REX640 Technical Manual ...

Page 1453: ...age in volt is available for application configurations through output U_INST_A U_INST_B and U_INST_C Phase voltage demand value in volt is for connecting to Load profile recorder LDPRLRC through output U_DMD_A U_DMD_B and U_DMD_C 8 1 6 4 Analog channel configuration VPHMMXU has one analog group input which must be properly configured Table 1377 Analog inputs Input Description U3P Three phase volt...

Page 1454: ...ch with certain settings For troubleshooting check the content of this chapter and also the preprocessing blocks in this document The configuration can be written to the protection relay once the mismatch is corrected 8 1 6 5 Signals VPHMMXU Input signals Table 1379 VPHMMXU Input signals Name Type Default Description U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for all bi nar...

Page 1455: ...01 1 40 High alarm voltage limit V high limit 0 00 5 00 xUn 0 01 1 20 High warning volt age limit V low limit 0 00 5 00 xUn 0 01 0 00 Low warning volt age limit V low low limit 0 00 5 00 xUn 0 01 0 00 Low alarm voltage limit V deadband 100 100000 1 10000 Deadband configu ration value for in tegral calculation percentage of dif ference between min and max as 0 001 s Table 1382 VPHMMXU Non group set...

Page 1456: ...angle U_DMD_A FLOAT32 0 00 5 00 xUn Demand value of UL1 voltage U_RANGE_A Enum UL1 amplitude range U_INST_B FLOAT32 0 00 5 00 xUn UL2 amplitude magni tude of instantaneous value U_ANGL_B FLOAT32 180 00 180 00 deg UL2 angle U_DMD_B FLOAT32 0 00 5 00 xUn Demand value of UL2 voltage U_RANGE_B Enum UL2 amplitude range U_INST_C FLOAT32 0 00 5 00 xUn UL3 amplitude magni tude of instantaneous value U_ANG...

Page 1457: ...teristic Value At voltages in range 0 01 1 15 Un 0 5 or 0 002 Un Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 RMS No suppression 1MRS759142 F Measurement functions REX640 Technical Manual 1457 ...

Page 1458: ...nfigurations through output U_INST Phase voltage demand value in volt is for connecting to Load profile recorder LDPRLRC through output U_DMD 8 1 7 4 Analog channel configuration VAMMXU has one analog group input which must be properly configured Table 1385 Analog inputs Input Description U3P Voltage group signal See the preprocessing function blocks in this document for the possible signal source...

Page 1459: ...m HIGH_WARN BOOLEAN High warning LOW_WARN BOOLEAN Low warning LOW_ALARM BOOLEAN Low alarm U_INST_AB FLOAT32 Phase AB voltage instantane ous value amplitude in kV U_INST_BC FLOAT32 Phase BC voltage instantane ous value amplitude in kV U_INST_CA FLOAT32 Phase CA voltage instantane ous value amplitude in kV U_INST_A FLOAT32 Phase A voltage instantane ous value amplitude in kV U_INST_B FLOAT32 Phase B...

Page 1460: ...dvanced Parameter Values Range Unit Step Default Description Measurement mode 1 RMS 2 DFT 2 DFT Selects used meas urement mode On delay time 0 1800000 ms 100 0 Delay the activation of the alarm and warning outputs Off delay time 0 1800000 ms 100 0 Delay the deactiva tion of the alarm and warning out puts 8 1 7 7 VMMXU Monitored data Table 1391 VMMXU Monitored data Name Type Values Range Unit Descr...

Page 1461: ...m 0 normal 1 high 2 low 3 high high 4 low low U12 amplitude range U_INST_BC FLOAT32 0 00 4 00 xUn U23 amplitude magni tude of instantaneous value U_ANGL_BC FLOAT32 180 00 180 00 deg U23 angle U_DB_BC FLOAT32 0 00 4 00 xUn U23 amplitude magni tude of deadband value U_DMD_BC FLOAT32 0 00 4 00 xUn Demand value of U23 voltage U_RANGE_BC Enum 0 normal 1 high 2 low 3 high high 4 low low U23 amplitude ra...

Page 1462: ...80 00 180 00 deg UL3 angle U_DMD_C FLOAT32 0 00 5 00 xUn Demand value of UL3 voltage 8 1 7 8 Technical data Table 1392 VAMMXU Technical data Characteristic Value Operation accuracy Depending on the frequency of the voltage measured fn 2 Hz At voltages in range 0 01 1 15 Un 0 5 or 0 002 Un Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 RMS No suppression 8 1 8 Residual current measure...

Page 1463: ... measured or calculated See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this document The configuration can b...

Page 1464: ...on group settings Advanced Parameter Values Range Unit Step Default Description Measurement mode 1 RMS 2 DFT 2 DFT Selects used meas urement mode On delay time 0 1800000 ms 100 0 Delay the activation of the alarm and warning outputs Off delay time 0 1800000 ms 100 0 Delay the deactiva tion of the alarm and warning out puts 8 1 8 7 RESCMMXU Monitored data Table 1398 RESCMMXU Monitored data Name Typ...

Page 1465: ...Timestamp Time of maximum de mand residual current Time min demand Io Timestamp Time of minimum de mand residual current 8 1 8 8 Technical data Table 1399 RESCMMXU Technical data Characteristic Value Operation accuracy At the frequency f fn 0 5 or 0 002 In at currents in the range of 0 01 4 00 In Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 RMS No suppression 8 1 9 Residual voltage...

Page 1466: ...is document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 1401 Special conditions Condition Description URES calculated The function requires that all three voltage channels are connected to calculate residu al voltage Setting VT connection must be Wye in that particular UTVTR Improper analog channel configuration causes a valid...

Page 1467: ...d configu ration value for in tegral calculation percentage of dif ference between min and max as 0 001 s Table 1405 RESVMMXU Non group settings Advanced Parameter Values Range Unit Step Default Description Measurement mode 1 RMS 2 DFT 2 DFT Selects used meas urement mode On delay time 0 1800000 ms 100 0 Delay the activation of the alarm and warning outputs Off delay time 0 1800000 ms 100 0 Delay ...

Page 1468: ...2 low 3 high high 4 low low Residual voltage Ampli tude range 8 1 9 8 Technical data Table 1407 RESVMMXU Technical data Characteristic Value Operation accuracy Depending on the frequency of the measured voltage f fn 2 Hz 0 5 or 0 002 Un Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 RMS No suppression 8 1 10 Frequency measurement FMMXU ANSI f 8 1 10 1 Identification Function descript...

Page 1469: ...z which is available for application configurations through output F_INST 8 1 10 4 Signals FMMXU Input signals Table 1408 FMMXU Input signals Name Type Default Description U3P SIGNAL Three phase voltages FMMXU Output signals Table 1409 FMMXU Output signals Name Type Description F_INST FLOAT32 Frequency instantaneous val ue 8 1 10 5 FMMXU Settings Table 1410 FMMXU Non group settings Basic Parameter...

Page 1470: ... 35 00 75 00 Hz Frequency instantane ous value F_DB FLOAT32 35 00 75 00 Hz Frequency deadband value F_RANGE Enum 0 normal 1 high 2 low 3 high high 4 low low Measured frequency range 8 1 10 7 Technical data Table 1413 FMMXU Technical data Characteristic Value Operation accuracy 5 mHz in measurement range 35 75 Hz 8 1 11 Sequence current measurement CSMSQI ANSI I1 I2 I0 8 1 11 1 Identification Funct...

Page 1471: ...r application configurations through outputs I2_INST I1_INST and I0_INST 8 1 11 4 Analog channel configuration CSMSQI has one analog group input which must be properly configured Table 1414 Analog inputs Input Description I3P Three phase currents See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configuration causes a validation error if...

Page 1472: ...ce low warn ing I1_LOW_AL BOOLEAN Positive sequence low alarm I0_HIGH_AL BOOLEAN Zero sequence high alarm I0_HIGH_WARN BOOLEAN Zero sequence high warning I2_INST FLOAT32 Negative sequence current amplitude instantaneous val ue A I1_INST FLOAT32 Positive sequence current amplitude instantaneous val ue A I0_INST FLOAT32 Zero sequence current ampli tude instantaneous value A 8 1 11 6 CSMSQI Settings ...

Page 1473: ... neg ative sequence cur rent Ng Seq A low limit 0 00 40 00 xIn 0 01 0 00 Low warning cur rent limit for neg ative sequence cur rent Ng Seq A low low Lim 0 00 40 00 xIn 0 01 0 00 Low alarm current limit for negative sequence current Ng Seq A deadband 100 100000 1 2500 Deadband configu ration value for negative sequence current for inte gral calculation percentage of dif ference between min and max ...

Page 1474: ...me 0 1800000 ms 100 0 Delay the deactiva tion of the alarm and warning out puts for zero se quence current 8 1 11 7 CSMSQI Monitored data Table 1419 CSMSQI Monitored data Name Type Values Range Unit Description NgSeq A 1 FLOAT32 0 00 40 00 xIn Measured negative se quence current PsSeq A 1 FLOAT32 0 00 40 00 xIn Measured positive se quence current ZrSeq A 1 FLOAT32 0 00 40 00 xIn Measured zero se q...

Page 1475: ...0 00 xIn Positive sequence cur rent amplitude dead band value I1_RANGE Enum 0 normal 1 high 2 low 3 high high 4 low low Positive sequence cur rent amplitude range I0_INST FLOAT32 0 00 40 00 xIn Zero sequence current amplitude instantane ous value I0_ANGL FLOAT32 180 00 180 00 deg Zero sequence current angle I0_DB FLOAT32 0 00 40 00 xIn Zero sequence current amplitude deadband value I0_RANGE Enum 0...

Page 1476: ...q V off delay time Ng Seq V on delay time Ng Seq V off delay time Zro Seq V on delay time and Zro Seq V off delay time are used for controlling the activation and the deactivation of alarm and warning outputs Instantaneous sequence voltages in volt are available for application configurations through outputs U2_INST U1_INST and U0_INST 8 1 12 4 Analog channel configuration VSMSQI has one analog gr...

Page 1477: ...ignals Table 1423 VSMSQI Input signals Name Type Default Description U3P SIGNAL Three phase voltages VSMSQI Output signals Table 1424 VSMSQI Output signals Name Type Description U2_HIGH_AL BOOLEAN Negative sequence high alarm U2_HIGH_WARN BOOLEAN Negative sequence high warning U1_HIGH_AL BOOLEAN Positive sequence high alarm U1_HIGH_WARN BOOLEAN Positive sequence high warn ing U1_LOW_WARN BOOLEAN P...

Page 1478: ...age limit for positive sequence voltage Ps Seq V deadband 100 100000 1 10000 Deadband configu ration value for positive sequence voltage for inte gral calculation percentage of dif ference between min and max as 0 001 s Ng Seq V Hi high Lim 0 00 4 00 xUn 0 01 0 20 High alarm voltage limit for negative sequence voltage Ng Seq V High limit 0 00 4 00 xUn 0 01 0 05 High warning volt age limit for nega...

Page 1479: ...Seq V off delay time 0 1800000 ms 100 0 Delay the deactiva tion of the alarm and warning out puts for positive sequence voltage Ng Seq V on delay time 0 1800000 ms 100 0 Delay the activa tion of the alarm and warning out puts for negative sequence voltage Ng Seq V off delay time 0 1800000 ms 100 0 Delay the deactiva tion of the alarm and warning out puts for negative sequence voltage Zro V on dela...

Page 1480: ...e volt age angle U2_DB FLOAT32 0 00 4 00 xUn Negative sequence volt age amplitude dead band value U2_RANGE Enum 0 normal 1 high 2 low 3 high high 4 low low Negative sequence volt age amplitude range U1_INST FLOAT32 0 00 4 00 xUn Positive sequence volt age amplitude instan taneous value U1_ANGL FLOAT32 180 00 180 00 deg Positive sequence volt age angle U1_DB FLOAT32 0 00 4 00 xUn Positive sequence ...

Page 1481: ... 1 13 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Three phase power and energy measurement PEMMXU P E P E 8 1 13 2 Function block Figure 815 Function block 8 1 13 3 Functionality The three phase power and energy measurement function PEMMXU calculates energy and power from the available current and voltage inputs The function...

Page 1482: ...9 Analog inputs Input Description I3P Three phase currents U3P Three phase voltages See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 1430 Special conditions Condition Description U3P connected to real meas urements The function can work with the corresponding one voltage channe...

Page 1483: ...Power factor magnitude of instantaneous value EAFPULSE SIGNAL Accumulated forward active energy pulse EARPULSE SIGNAL Accumulated reverse active energy pulse ERFPULSE SIGNAL Accumulated forward reac tive energy pulse ERRPULSE SIGNAL Accumulated reverse reactive energy pulse S_DMD FLOAT32 Demand value of apparent power P_DMD FLOAT32 Demand value of active pow er Q_DMD FLOAT32 Demand value of reacti...

Page 1484: ...4 PEMMXU Non group settings Advanced Parameter Values Range Unit Step Default Description Forward Wh Initial 0 999999999 1 0 Preset Initial value for forward active energy Reverse Wh Initial 0 999999999 1 0 Preset Initial value for reverse active energy Forward VArh Initial 0 999999999 1 0 Preset Initial value for forward reactive energy Reverse VArh Initial 0 999999999 1 0 Preset Initial value fo...

Page 1485: ... kVAr Demand value of reac tive power PF_INST FLOAT32 1 00 1 00 Power factor magni tude of instantaneous value PF_DB FLOAT32 1 00 1 00 Power factor magni tude of deadband value PF_DMD FLOAT32 1 00 1 00 Demand value of power factor EA_RV_ACM INT64 0 999999999 kWh Accumulated reverse active energy value ER_RV_ACM INT64 0 999999999 kVArh Accumulated reverse re active energy value EA_FWD_ACM INT64 0 9...

Page 1486: ... At the frequency f n 1 Hz 1 5 for apparent power S 1 5 for active power P and active energy 2 1 5 for reactive power Q and reactive en ergy 3 0 015 for power factor Suppression of harmonics DFT 50 dB at f n fn where n 2 3 4 5 8 2 Disturbance recorder common functionality RDRE ANSI DFR 8 2 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 devic...

Page 1487: ...lication Configuration in PCM600 In addition each channel of the disturbance recorder can be enabled or disabled by setting the Operation parameter of the corresponding channel to on or off All channels of the disturbance recorder that are enabled and have a valid signal connected are included in the recording 8 2 3 2 Triggering alternatives The recording can be triggered by any of the following a...

Page 1488: ...ation and therefore the recorder does not trigger This is useful especially in undervoltage situations The filter time of approximately 50 ms is common to all the analog channel triggers of the disturbance recorder The value used for triggering is the calculated peak to peak value Either high or low analog channel trigger can be disabled by setting the corresponding trigger level parameter to zero...

Page 1489: ...e recorder the sampling frequency of binary channels is 400 Hz at the rated frequency of 50 Hz and 480 Hz at the rated frequency of 60 Hz Table 1437 Sampling frequencies of the disturbance recorder analog and binary channels Storage rate samples per fundamental cycle Recording length Rated frequency 50 Hz Rated frequency 60 Hz Sampling frequency of analog channels Sampling frequency of binary chan...

Page 1490: ... corresponding COMTRADE files CFG and DAT are deleted Both file types may need to be deleted separately depending on the software used Deleting all disturbance recordings at once is done either with PCM600 or any appropriate computer software or from the LHMI via the Clear Disturbance records menu Deleting all disturbance recordings at once also clears the pre trigger recording in progress 8 2 3 7...

Page 1491: ...tion mode of the disturbance recorder can be changed with the Operation mode parameter Saturation mode In saturation mode the captured recordings cannot be overwritten with new recordings Capturing the data is stopped when the recording memory is full that is when the maximum number of recordings is reached In this case the event is sent via the state change TRUE of the Memory full parameter When ...

Page 1492: ...l menu One analog signal type of the protection relay can be mapped to each of the analog channels of the disturbance recorder The mapping is done in Application Configuration in PCM600 The name of the analog channel is user configurable It can be modified by defining a new name to the Channel id text parameter of the corresponding analog channel Channel id text can be edited in Application Config...

Page 1493: ...ue of the Bay name parameter are both included in the COMTRADE configuration file for identification purposes 8 2 5 Application The disturbance recorder is used for post fault analysis and for verifying the correct operation of protection relays and circuit breakers It can record both analog and binary signal information The analog inputs are recorded as instantaneous values and converted to prima...

Page 1494: ...torage rate of the waveform re cording Periodic trig time 0 604 800 s 10 0 Time between peri odic triggerings Stor mode periodic 0 Waveform 1 Trend cycle 1 0 Storage mode for periodic triggering Stor mode manual 0 Waveform 1 Trend cycle 1 0 Storage mode for manual triggering Table 1441 RDRE Control data basic Parameter Values Range Unit Step Default Description Trig recording 0 Cancel 1 Trig 0 Can...

Page 1495: ...o the next periodic triggering 8 3 Disturbance recorder analog channels 1 24 A1RADR and A2RADR 8 3 1 Function block Figure 818 Function block 8 3 2 Signals The input signal tables for A1RADR and A2RADR are similar except for the channel numbers A1RADR CH1 CH12 A2RADR CH13 CH24 Table 1443 A1RADR Input signals Name Type Default Description CH1 SIGNAL Signal for input 1 1MRS759142 F Measurement funct...

Page 1496: ...cription Operation 1 on 5 off 1 on Analog channel on off Channel id text Analog ch 1 input Channel identifier text High trigger level 0 00 60 00 0 01 10 Over limit Low trigger level 0 00 2 00 0 01 0 Under limit Table 1445 A1RADR Non group general settings advanced Parameter Values Range Unit Step Default Description Storage mode 0 Waveform 1 Trend cycle 0 Storage mode se lection waveform trend 8 4...

Page 1497: ...the same for each input signal The channel numbers are shown after the parameter name in the HMI and PCM600 8 4 3 Settings Setting tables for all B1RBDR and B2RBDR channels are similar except for the channel numbers Table 1447 B1RBDR Non group general settings basic Parameter Values Range Unit Step Parameter Values Range Unit Step Default Description Operation 1 on 5 off Binary channel on off Tabl...

Page 1498: ...C ANSI 84T 8 5 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Tap changer position indication TPOSYLTC TPOSM 84T 8 5 2 Function block Figure 820 Function block 8 5 3 Functionality The tap changer position indication function TPOSYLTC is used for transformer tap position supervision The binary inputs can be used for converting a...

Page 1499: ...AP_POS connector the binary inputs are expected to be used for the tap changer position information The tap changer position value and quality are internally shared to other functions The value is available in the Monitored data view or as a TAP_POS output signal The function has three alternative user selectable operation modes NAT2INT BCD2INT and GRAY2INT The operation mode is selected with the ...

Page 1500: ...he quality is set to bad For negative values when the SIGN_BIT is set to TRUE 1 and the input binary combination is 1011011 the quality is set to bad If the tap changer has auxiliary contacts for indicating the extreme positions of the tap changer their status can be connected to END_POS_R and END_POS_L inputs The END_POS_R End position raise or highest allowed tap position reached status refers t...

Page 1501: ... 19 20 0 0 1 1 1 1 1 31 19 21 0 1 0 0 0 0 0 32 20 63 0 1 0 0 0 0 1 33 21 62 0 1 0 0 0 1 0 34 22 60 0 1 0 0 0 1 1 35 23 61 0 1 0 0 1 0 0 36 24 56 8 5 5 Application TPOSYLTC provides tap position information for other functions as a signed integer value that can be fed to the tap position input The position information of the tap changer can be coded in various methods for many applications for exam...

Page 1502: ... tap position information can be fed to TPOSYLTC When there is a wired connection to the TAP_POS connector the validated tap changer position is presented in the TAP_POS output that is connected to other functions for example OL5ATCC1 When there is no wired connection to the TAP_POS connector the binary inputs are expected to be used for the tap changer position information Figure 822 RTD analog i...

Page 1503: ...1 on 5 off 1 on Operation Off On Operation mode 1 NAT2INT 2 BCD2INT 3 GRAY2INT 2 BCD2INT Operation mode selection 8 5 8 TPOSYLTC Monitored data Table 1453 TPOSYLTC Monitored data Name Type Values Range Unit Description BI0 BOOLEAN 0 False 1 True Binary input 1 BI1 BOOLEAN 0 False 1 True Binary input 2 BI2 BOOLEAN 0 False 1 True Binary input 3 BI3 BOOLEAN 0 False 1 True Binary input 4 BI4 BOOLEAN 0...

Page 1504: ...reached END_POS_L BOOLEAN 0 False 1 True End position lower or lowest allowed tap po sition reached TAP_POS INT8 63 63 Tap position indication 8 5 9 Technical data Table 1454 TPOSYLTC Technical data Description Value Response time for binary inputs Typical 100 ms Measurement functions 1MRS759142 F 1504 REX640 Technical Manual ...

Page 1505: ...entification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Circuit breaker control CBXCBR I O CB 52 Disconnector control DCXSWI I O DCC 29DS Earthing switch control ESXSWI I O ESC 29GS 9 1 2 Function block Figure 823 Function block 1MRS759142 F Control functions REX640 Technical Manual 1505 ...

Page 1506: ...short disturbances in an input are eliminated by filtering The binary input filtering time can be adjusted separately for each digital input used by the function block The validity of the digital inputs that indicate the object state is used as additional information in indications and event logging The reporting of faulty or intermediate position of the apparatus occurs after the Event delay sett...

Page 1507: ...BLK_CLOSE CLOSE_ENAD ENA_OPEN ITL_BYPASS OPEN_ENAD BLK_OPEN SYNC_BYPASS OR AND Figure 824 Enabling and blocking logic for CLOSE_ENAD and OPEN_ENAD signals Disconnector control DCXSWI and earthing switch control ESXSWI Normally the switch closing is enabled that is the CLOSE_ENAD signal is TRUE by activating the ENA_CLOSE input The input ITL_BYPASS can be used for bypassing this control The ITL_BYP...

Page 1508: ...king conditions the pulse output CTL_ITL_BLKD is activated The length of the pulse is defined by the Interlocking Pls Len setting When close command is given from communication via LHMI or activating the AU_CLOSE input it is carried out the EXE_CL output only if CLOSE_ENAD is TRUE If the SECRSYN function is used in Command mode the CL_REQ output can be used in CBXCBR Initially the SYNC_OK input is...

Page 1509: ...CBXCBR OPEN and CLOSE outputs The EXE_OP output is activated when the open command is given AU_OPEN via communication or from LHMI and OPEN_ENAD signal is TRUE In addition the protection trip commands can be routed through the CBXCBR function by using the TRIP input When the TRIP input is TRUE the EXE_OP output is activated immediately and bypassing all enabling or blocking conditions The EXE_CL o...

Page 1510: ...he maximum pulse length is given Pulse length setting does not affect the length of the opening pulse when EXE_OP is activated via TRIP input EXE_OP will remain active as long as TRIP input is active Control methods The command execution mode can be set with the Control model setting The alternatives for command execution are direct control and secured object control which can be used to secure co...

Page 1511: ...g is needed However in case of simultaneous open and close control the open control is always prioritized 1 Send reservationto other terminals 2 Receive response Selected to operate REF 615 REF 615 REF 615 REF 615 REF 615 Figure 829 Control procedure in the SBO method Local Remote operations The local remote selection affects CBXCBR DCXSWI and ESXSWI Local the opening and closing via communication...

Page 1512: ...using the IEC 61850 GOOSE messages between feeders Control and interlocking via GOOSEmessages REF 615 REF 615 REF 615 REF 615 Figure 830 Status indication based interlocking via the GOOSE messaging 9 1 6 Signals 9 1 6 1 CBXCBR Input signals Table 1456 CBXCBR Input signals Name Type Default Description POSOPEN BOOLEAN 0 False Signal for open po sition of apparatus from I O POSCLOSE BOOLEAN 0 False ...

Page 1513: ...9 1 6 2 DCXSWI Input signals Table 1457 DCXSWI Input signals Name Type Default Description POSOPEN BOOLEAN 0 False Signal for open po sition of apparatus from I O POSCLOSE BOOLEAN 0 False Signal for close po sition of apparatus from I O ENA_OPEN BOOLEAN 1 True Enables opening ENA_CLOSE BOOLEAN 1 True Enables closing BLK_OPEN BOOLEAN 0 False Blocks opening BLK_CLOSE BOOLEAN 0 False Blocks closing A...

Page 1514: ...scards ENA_OPEN and ENA_CLOSE in terlocking when TRUE 9 1 6 4 CBXCBR Output signals Table 1459 CBXCBR Output signals Name Type Description SELECTED BOOLEAN Object selected EXE_OP BOOLEAN Executes the command for open direction EXE_CL BOOLEAN Executes the command for close direction OP_REQ BOOLEAN Open request CL_REQ BOOLEAN Close request OPENPOS BOOLEAN Apparatus open position CLOSEPOS BOOLEAN App...

Page 1515: ...LKD BOOLEAN Control is blocked due to in terlocking 9 1 6 6 ESXSWI Output signals Table 1461 ESXSWI Output signals Name Type Description SELECTED BOOLEAN Object selected EXE_OP BOOLEAN Executes the command for open direction EXE_CL BOOLEAN Executes the command for close direction OPENPOS BOOLEAN Apparatus open position CLOSEPOS BOOLEAN Apparatus closed position OKPOS BOOLEAN Apparatus position is ...

Page 1516: ...aptive pulse 0 False 1 True 1 True Deactivate control pulse when appa ratus has reached correct position Event delay 0 10000 ms 1 200 Event delay of the intermediate and faulty position Interlocking Pls Len 1 10 s 1 2 Pulse length for in terlocking violation signal Vendor 0 External equipment vendor Serial number 0 External equipment serial number Model 0 External equipment model 9 1 7 2 DCXSWI Se...

Page 1517: ...XSWI Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation mode on off Select timeout 10000 300000 ms 10000 30000 Select timeout in ms Pulse length 10 60000 ms 1 100 Open and close pulse length Control model 0 status only 1 direct with nor mal security 4 sbo with en hanced security 4 sbo with en hanced security Select control mod el Opera...

Page 1518: ...scription POSITION Dbpos 0 intermediate 1 open 2 closed 3 faulty Apparatus position in dication 9 1 8 2 DCXSWI Monitored data Table 1469 DCXSWI Monitored data Name Type Values Range Unit Description POSITION Dbpos 0 intermediate 1 open 2 closed 3 faulty Apparatus position in dication 9 1 8 3 ESXSWI Monitored data Table 1470 ESXSWI Monitored data Name Type Values Range Unit Description POSITION Dbp...

Page 1519: ... 1 9 2 Technical revision history Table 1472 DCXSWI Technical revision history Product connectivi ty level Technical revision Change PCL4 E New output CTL_ITL_BLKD and pulse timer setting Interlocking Pls Len added 9 1 9 3 Technical revision history Table 1473 ESXSWI Technical revision history Product connectivi ty level Technical revision Change PCL4 E New output CTL_ITL_BLKD and pulse timer sett...

Page 1520: ... switchgear GIS P3SXSWI executes commands to RIO600 SCM or directly drives the switchgear motor by direct control of the protection relay s H bridge if available The function evaluates blocking conditions and different supervision conditions and it performs an execution command only if all conditions are fulfilled If erroneous conditions occur the function indicates an appropriate cause value The ...

Page 1521: ...d validity check Depending on the switch type connection a three position switch disconnector or earthing switch can be configured Be aware of the physical switch type and corresponding connections in Application Configuration both for P3SXSWI and in RIO600 SCM if used A wrong connection according to the physical switch type can cause misleading position indication In certain three position switch...

Page 1522: ...Faulty 0 1 1 0 0 2 0 1 0 0 0 Faulty 0 1 1 1 x 0 1 0 0 0 Faulty 1 1 0 1 x 0 0 0 1 0 Faulty 1 x 1 x x 0 0 0 0 0 Faulty x 0 x 0 x 0 0 0 0 0 x no difference The REED input is only supervised during a short time window when earthing switch has closed and if Reed contact setting is set as Available in direct control mode When a two position switch type is used only the corresponding outputs are enabled ...

Page 1523: ...IO600 SCM the switch s position information should be made available to the function in the protection relay via GOOSE or binary inputs from RIO600 to reflect correct position and status information 9 2 4 2 Control of a three position switch There are three possible end positions in a three position switch earthing switch closed both open and disconnector closed Additionally there are two intermed...

Page 1524: ...des a general interlocking bypass input ITL_BYPASS When ITL_BYPASS is TRUE the apparatus can be controlled by discarding the ENA_DCOPEN ENA_DCCLOSE ENA_ESOPEN and ENA_ESCLOSE input states However the BLK_DCOPEN BLK_DCCLOSE BLK_ESOPEN and BLK_ESCLOSE input signals are not bypassed with the interlocking bypass functionality since they always have higher priority In Table 1477 the interlocking condit...

Page 1525: ... commands there are enabling and blocking functionalities for all the operations If the control command is executed against the blocking or if the enabling of the corresponding command is not valid the function generates an error message If the control is inhibited due to interlocking conditions the pulse output CTL_ITL_BLKD is activated The length of the pulse is defined by the Interlocking Pls L...

Page 1526: ...returned to the protection relay via GOOSE The inputs for P3SXSWI shown in Figure 833 must be connected by GOOSE status signals from SCM Input REED remains unconnected in this control mode SCMLPGGIO1 Ind10 stVal SCMLPGGIO1 Ind11 stVal SCMLPGGIO1 Ind12 stVal SCMLPGGIO1 Ind13 stVal SCMLPGGIO1 Ind14 stVal SCMLPGGIO1 Ind15 stVal SCMLPGGIO1 Ind16 stVal SCMLPGGIO1 Ind17 stVal SCMLPGGIO1 Ind1 stVal SCMLP...

Page 1527: ...CS SPO8 Uaux Uaux H_UP_LEFT H_UP_RIGHT H_LO_LEFT H_LO_RIGHT M Figure 834 H bridge motor control for a protection relay equipped with BIO1002 module Table 1478 H bridge motor operation depending on active outputs Motor direction Static outputs H_UP_LEFT H_UP_RIGHT H_LO_LEFT H_LO_RIGHT Motor right 1 0 0 1 Motor left 0 1 1 0 Motor brake 1 1 0 0 Motor brake 0 0 1 1 Motor free 0 0 0 0 Be aware of the m...

Page 1528: ...fter the motor has braked and stopped the motor is in a free state meaning that the switch is mechanically operable by hand crank A successful operation is also displayed on the HMI or reported via communication After each operation the motor is paused for one second before any new control command can pass through 9 2 4 7 Control methods The command execution mode can be set with the Control model...

Page 1529: ...ee state earthing switch closed disconnector closed and both open switches The function also handles user defined interlocking logics and provides commands Control and status indication facilities are implemented in the same package with P3SXSWI When primary components are controlled in the energizing phase for example the correct execution sequence of the control command must be ensured This can ...

Page 1530: ...messaging Earthing contact Disconnector contact Sliding part Fixed contact Insulating spindle Protection relay Motor Motor control Position contacts Reed contact Figure 837 Connection diagram for direct control of a three position switchgear motor Control functions 1MRS759142 F 1530 REX640 Technical Manual ...

Page 1531: ...E_ESCLOSE and EXE_ESOPEN are connected in Application Configuration When direct motor control is selected as control mode static outputs H_UP_LEFT H_UP_RIGHT H_LO_LEFT and H_LO_RIGHT are connected in Application Configuration 9 2 6 Signals 9 2 6 1 P3SXSWI Input signals Table 1479 P3SXSWI Input signals Name Type Default Description DCPOSOPEN BOOLEAN 0 False Signal for open posi tion of disconnector...

Page 1532: ...or BLK_DCCLOSE BOOLEAN 0 False Blocks closing of dis connector BLK_ESOPEN BOOLEAN 0 False Blocks opening of earthing switch BLK_ESCLOSE BOOLEAN 0 False Blocks closing of earthing switch AU_DCOPEN BOOLEAN 0 False Auxiliary open discon nector AU_DCCLOSE BOOLEAN 0 False Auxiliary close dis connector AU_ESOPEN BOOLEAN 0 False Auxiliary open earth ing switch AU_ESCLOSE BOOLEAN 0 False Auxiliary close e...

Page 1533: ... ESCLOSE_ENAD BOOLEAN Earthing switch closing is en abled DCOPEN_POS BOOLEAN Disconnector in open posi tion DCCLOSE_POS BOOLEAN Disconnector in closed posi tion ESOPEN_POS BOOLEAN Earthing switch in open posi tion ESCLOSE_POS BOOLEAN Earthing switch in closed po sition OKPOS BOOLEAN Apparatus position is ok EXE_DCOPEN BOOLEAN Command to RIO600 SCM for opening disconnector EXE_DCCLOSE BOOLEAN Comma...

Page 1534: ...meout DC 10 60000 ms 1 30000 Timeout for nega tive termination for disconnector Operation timeout ES 10 60000 ms 1 30000 Timeout for nega tive termination for earthing switch Motor braking 0 False 1 True 1 True Motor braking on off selection Identification P3SXSWI1 switch position Control object identification Table 1482 P3SXSWI Non group settings Advanced Parameter Values Range Unit Step Default ...

Page 1535: ...losed 5 faulty 3 position switch posi tion POSITION_DC Dbpos 0 intermediate 1 open 2 closed 3 faulty Disconnector position POSITION_ES Dbpos 0 intermediate 1 open 2 closed 3 faulty Earthing switch posi tion SWTYPE Enum 1 3 position switch 2 Disconnector 3 Earthing switch 4 Unknown Switch type 9 2 9 Technical revision history Table 1484 P3SXSWI Technical revision history Product connectivi ty level...

Page 1536: ...cate safe earthing The contact is TRUE only when the earthing switch is in closed position The reed contact is given a short time window to confirm closed earthing switch position in case of vibrations If the earthing switch has closed but the reed contact does not close within the time window faulty position is reported The availability of the reed contact needs to be set through Reed contact set...

Page 1537: ...lty x 0 x 0 x 0 0 0 0 0 x no difference The REED input is only supervised during a short time window when earthing switch has closed and if Reed contact setting is set as Available 9 3 5 Application In the field of distribution and sub transmission automatic reliable control and status indication of primary switching components both locally and remotely is of significant importance They are needed...

Page 1538: ...utput signals Table 1487 P3SSXSWI Output signals Name Type Description DCOPEN_POS BOOLEAN Disconnector in open posi tion DCCLOSE_POS BOOLEAN Disconnector in closed posi tion ESOPEN_POS BOOLEAN Earthing switch in open posi tion ESCLOSE_POS BOOLEAN Earthing switch in closed po sition OKPOS BOOLEAN Apparatus position is ok 9 3 7 P3SSXSWI Settings Table 1488 P3SSXSWI Non group settings Basic Parameter...

Page 1539: ...ter mediate 2 both open 3 disconnector inter mediate 4 disconnector closed 5 faulty 3 position switch posi tion POSITION_DC Dbpos 0 intermediate 1 open 2 closed 3 faulty Disconnector position POSITION_ES Dbpos 0 intermediate 1 open 2 closed 3 faulty Earthing switch posi tion 9 4 Disconnector position indicator DCSXSWI and Earthing switch position indication ESSXSWI ANSI 29DS 29GS 9 4 1 Identificat...

Page 1540: ...efined by the two digital inputs POSOPEN and POSCLOSE which are also available as outputs OPENPOS and CLOSEPOS together with the OKPOS according to Table 1491 The debounces and short disturbances in an input are eliminated by filtering The binary input filtering time can be adjusted separately for each digital input used by the function block The validity of digital inputs that indicate the object...

Page 1541: ...6 Signals 9 4 6 1 DCSXSWI Input signals Table 1492 DCSXSWI Input signals Name Type Default Description POSOPEN BOOLEAN 0 False Signal for open po sition of apparatus from I O POSCLOSE BOOLEAN 0 False Signal for close po sition of apparatus from I O 9 4 6 2 ESSXSWI Input signals Table 1493 ESSXSWI Input signals Name Type Default Description POSOPEN BOOLEAN 0 False Signal for open po sition of appar...

Page 1542: ...00 ms 1 30000 Event delay of the intermediate and faulty position Vendor 0 External equipment vendor Serial number 0 External equipment serial number Model 0 External equipment model 9 4 7 2 ESSXSWI Settings Table 1498 ESSXSWI Non group settings Basic Parameter Values Range Unit Step Default Description Identification ESSXSWI1 switch position Control Object identification Table 1499 ESSXSWI Non gr...

Page 1543: ...tored data Name Type Values Range Unit Description POSITION Dbpos 0 intermediate 1 open 2 closed 3 faulty Apparatus position in dication 9 5 Synchronism and energizing check SECRSYN ANSI 25 9 5 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Synchronism and energizing check SECRSYN SYNC 25 9 5 2 Function block Figure 842 Functio...

Page 1544: ...s which must be properly configured Table 1502 Analog inputs Input Description U3P1 Three phase voltages bus side U3P2 Three phase voltages line side See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 1503 Special conditions Condition Description U3P1 connected to real meas ureme...

Page 1545: ...e Synchro check function can operate either with the U_AB or U_A voltages The selection of used voltages is defined with the VT connection setting of the line voltage general parameters By default voltages U_BUS and U_LINE are connected as presented in Figure 852 If necessary connections can be switched by setting Voltage source switch to True Energizing check The Energizing check function checks ...

Page 1546: ...te is available as a monitored data value ENERG_STATE and as four function outputs LLDB live line dead bus LLLB live line live bus DLLB dead line live bus and DLDB dead line dead bus of which only one can be active at a time It is also possible that the measured energized state indicates Unknown if at least one of the measured voltages is between the limits set with the dead and live setting param...

Page 1547: ...se difference Depending on the circuit breaker and the closing system the delay from the moment the closing signal is given until the circuit breaker finally closes is about 50 250 ms The selected Closing time of CB informs the function how long the conditions have to persist The Synchro check function compensates for the measured slip frequency and the circuit breaker closing delay The phase angl...

Page 1548: ... to TRUE logic 1 and it stays TRUE as long as the conditions are fulfilled The command input is ignored in the continuous control mode SECRSYN CBXCBR I Closing permission Closing command Figure 845 A simplified block diagram of the Synchro check function in the continuous mode operation Command mode If Control mode is set to Command the purpose of the Synchro check functionality in the command mod...

Page 1549: ...ignal In the command control mode operation there are alarms for a failed closing attempt CL_FAIL_AL and for a command signal that remains active too long CMD_FAIL_AL If the conditions for closing are not fulfilled within the set time of Maximum Syn time a failed closing attempt alarm is given The CL_FAIL_AL alarm output signal is pulse shaped and the pulse length is 500 ms If the external command...

Page 1550: ... time 5s Figure 849 Determination of the alarm limit for a still active command signal Closing is permitted during Maximum Syn time starting from the moment the external command signal CL_COMMAND is activated The CL_COMMAND input must be kept active for the whole time that the closing conditions are waited to be fulfilled Otherwise the procedure is cancelled If the closing command conditions are f...

Page 1551: ...lication where the power transformer is located between the voltage measurement and the vector group connection gives phase difference to the voltages between the high and low voltage sides the angle adjustment can be used to meet synchronism U_Line U_Line U_Bus U_Bus ϕ Figure 850 Angle difference when power transformer is in sychrocheck zone The vector group of the power transformer is defined wi...

Page 1552: ...and B thus isolating the faulty section from the network and making the arc that caused the fault extinguish The first attempt to recover is a delayed autoreclosure made a few seconds later Then the autoreclose function DARREC gives a command signal to the synchrocheck function to close the circuit breaker A SECRSYN performs an energizing check as the line AB is de energized U_BUS Live bus value U...

Page 1553: ...voltage and U_LINE line voltage The wiring should be verified by checking the reading of the phase difference measured between the U_BUS and U_LINE voltages The phase difference measured by the protection relay has to be close to zero within the permitted accuracy tolerances The measured phase differences are indicated in the LHMI At the same time it is recommended to check the voltage difference ...

Page 1554: ...ription SYNC_INPRO BOOLEAN Synchronizing in progress SYNC_OK BOOLEAN Systems in synchronism CL_FAIL_AL BOOLEAN CB closing failed CMD_FAIL_AL BOOLEAN CB closing request failed LLDB BOOLEAN Live Line Dead Bus LLLB BOOLEAN Live Line Live Bus DLLB BOOLEAN Dead Line Live Bus DLDB BOOLEAN Dead Line Dead Bus 9 5 8 SECRSYN Settings Table 1508 SECRSYN Group settings Basic Parameter Values Range Unit Step D...

Page 1555: ...ng check Live bus value 0 2 1 0 xUn 0 1 0 5 Voltage high limit bus for energizing check Max energizing V 0 50 1 15 xUn 0 01 1 05 Maximum voltage for energizing Table 1510 SECRSYN Non group settings Advanced Parameter Values Range Unit Step Default Description Control mode 1 Continuous 2 Command 1 Continuous Selection of syn chro check com mand or Continu ous control mode Close pulse 200 60000 ms 1...

Page 1556: ...e out of limit for synchroniz ing PH_DIF_SYNC BOOLEAN 0 False 1 True Phase angle difference out of limit for synchro nizing FR_DIFF_SYNC BOOLEAN 0 False 1 True Frequency difference out of limit for synchro nizing SECRSYN Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 9 5 10 Technical data Table 1512 SECRSYN Technical data Characteristic Value Operation accuracy Depending on the frequency o...

Page 1557: ...uit breaker ASGCSYN includes the functionality of energizing check synchronization check and voltage and frequency matching The energizing check function checks that bus side is dead to ensure that breaker closing can be done safely The synchronization check function checks that the voltages and frequency on both sides of the circuit breaker are within the predefined setting It is used to perform ...

Page 1558: ...voltage channels from the bus side are connected to U3P2 The function can work if one voltage channel from the gener ator side is connected to channel 1 of U3P1 and two voltage channels along with the residual voltage from the bus side are connected to U3P2 The function can work if three voltage channels from the generator side are connected to U3P1 and one voltage chan nel from the bus side is co...

Page 1559: ..._U RAISE_F LOWER_F ISO_B_CLOSE EXT_CHECK GCB_TEST GOV_DROOP AVR_DROOP DROOP_GOV DROOP_AVR GOV_ALM_HI GOV_ALM_LO AVR_ALM_HI AVR_ALM_LO DIFF_U_ASC1 DIFF_F_ASC1 SYNC_INPRO SYNC_OK CL_FAIL_AL CMD_FAIL_AL GEN_ASC_DATA MATCH_INPRO MATCH_OK CLOSE_CB ASC1_GEN_DAT Energizing check MOD_CHG_GOV MOD_CHG_AVR U3P1 U3P2 CL_COMMAND U_A_AB U_B_BC U_C_CA BYPASS BLOCK U_A_AB Figure 854 Functional module diagram ASGC...

Page 1560: ...rator is given with the Dead voltage value setting Similarly the actual values of live bus or generator are defined with the Live voltage value setting When the energizing direction corresponds to the settings the situation has to be constant for a time set with the Energizing time setting before the circuit breaker closing is permitted This time delay ensures that the dead side remains de energiz...

Page 1561: ...H_DIFF_MEAS setting Phase shift is used to compensate the angle shift caused if a power transformer is located between the voltage measurements Offset correction due to different channel measurements for voltage and frequency values can be done using Voltage offset and Frequency offset The user can select the direction of generator synchronization using the setting Synchronization Dir U DIFF MEAS ...

Page 1562: ...he values Off Asynchronous Some additional conditions must also be fulfilled as per the set Synchrocheck mode Table 1516 Additional conditions for the Synchro check Measurements Synchrocheck mode Asynchronous U_DIFF_MEAS Voltage Diff Ov Ex and Voltage Diff Un Ex PH_DIFF_MEAS Angle Diff positive and Angle Diff nega tive FR_DIFF_MEAS Freq Diff OV Synch and Freq Diff sub Synch Closing angle Angle Dif...

Page 1563: ...uation 357 tCB Circuit breaker closing delay in ms TPL Output type dependent delay in ms see Table 1517 x Hardware delays between the protection relay and CB in ms delays due to for example auxiliary relays and contactors if used Table 1517 Typical delays for different output types Output type Recommended value for TPL Generator voltage measurement Non Adaptive Bus voltage measurement Non Adaptive...

Page 1564: ...ned below From the frequency slip s the acceleration ds dt the bus frequency FR_BUS_MEAS fBus and the set Closing time of CB the function calculates the necessary lead angle αLead by which the close CB command is shifted forward in time so that the main contacts close on phase coincidence αLead Bus f s TCB ds dt TCB 360 2 1000 1000 Equation 359 fBus Bus side frequency s Frequency slip ds dt Freque...

Page 1565: ...nput activation If GCB_TEST is activated CLOSE_CB is activated If GCB_TEST is deactivated and the bus and generator terminal voltages are both live or one side live CLOSE_CB is not activated Synchronization control The general bus bar arrangement for a generator bus is shown in Figure 857 The bus to which the generator is connected is determined based on the circuit breaker and isolator position i...

Page 1566: ...activate the closing signal CLOSE_CB In this auto synchronization mode once all the closing conditions are satisfied within the set Maximum Syn time the outputs SYNC_OK and CLOSE_CB become TRUE and remain active as long as the closing conditions are fulfilled If Multiple command is set to Off then only CLOSE_CB outputs are delivered once for each activated input signal as shown in Figure 858 If Mu...

Page 1567: ...nal is delivered The simplified configuration block diagram of ASGCSYN with CLOSE_CB to the breaker control function block is shown in Figure 860 I ASGCSYN CBXCBR CLOSE_CB AU_CLOSE EXE_CL SYNC_OK SYNC_OK Figure 860 Simplified configuration block diagram of ASGCSYN in auto synchronization mode operation Alarms generation In the synchro check command and auto synchronization control mode operation t...

Page 1568: ...he checking time the alarm CL_FAIL_AL is activated as an indication of a failed closing attempt The closing pulse is not delivered if the closing conditions become valid after Maximum Syn time has elapsed The closing pulse is delivered only once for each activated close command and a new closing command sequence cannot be started until the close command is reset and reactivated The circuit breaker...

Page 1569: ... frequency matching is activated automatically during the Autosynchronization mode Governor and AVR mode control If the setting Central PMS present is set to Yes then the governor and AVR mode is decided based on the inputs MODE_GOV and MODE_AVR respectively If the setting Central PMS present is set to No then the governor and AVR mode is decided based on the inputs DROOP_GOV and DROOP_AVR respect...

Page 1570: ...nerating governor raise or lower pulses to match the frequencies across the CB The voltage and frequency matching starts only when the ENERG_STATE is Both Live Voltage difference ΔU U_DIFF_MEAS Frequency difference ΔF FR_DIFF_MEAS Matching for network CB The generator is ready for network CB matching only when the generator CB is closed the protection relay is in remote mode and the generator is r...

Page 1571: ...eased Adjusting commands blocked Lower adjusting commands LOWER_U Direction of the adjusting commands depends on polarity of the U Figure 864 Working range of the voltage matcher If Auto Syn mode is set to either Semi automatic synchronizing mode or Automatic synchronizing mode the voltage raise or lower command pulses are generated from the function based on the voltage difference across the brea...

Page 1572: ...iable Pulse the voltage matching is done with variable command pulse lengths The voltage matcher issues a command with a length proportional to the voltage difference The proportionality factor setting Volt rate of change dU dt can be adapted to the voltage regulator The voltage matcher aims at a value in the middle of the set tolerance band The adjusting voltage command pulse length tpU is calcul...

Page 1573: ... Diff Ov Ex and Voltage Diff Un Ex as per Equation 361 tsU U U U Volt pulse off Intv 1 0 325 2 max max 0 Equation 361 ΔU Measured voltage difference across the CB to be synchronized ΔUmax Setting Voltage Diff Ov Ex ΔUmax Setting Voltage Diff Un Ex Reset of voltage raise and lower command pulses The generated voltage raise and lower command pulses RAISE_U and LOWER_U are immediately reset if any of...

Page 1574: ... stored the value from the output VOLT_CHG_RTE can be used to set the setting Volt rate of change This tuned voltage matching rate proceeds as follows 1 The generator voltage is adjusted until it lies in the range of 95 97 of the line voltage then the adjusting pulse is discontinued 2 Ten seconds after the first adjusting pulse the voltage difference ΔU0 is measured then a voltage raise command RA...

Page 1575: ...ive the reference side frequency is greater than the running side frequency So the frequency matching generates frequency raise command pulse RAISE_F If the frequency difference DF is positive it means the reference side frequency is lower than the running side frequency So the frequency matching generates frequency lower command pulse LOWER_F The length of the frequency raise and lower command pu...

Page 1576: ...able Pulse the frequency matching is done with variable command pulse lengths The frequency matcher issues a command with a length proportional to the current slip The proportionality factor df dt can be adapted to the governor The frequency matcher aims at a value midway between the nearer slip limit and zero The adjusting frequency command pulse length tpf is calculated as tpf s s df dt max 2 Eq...

Page 1577: ...f s Gen Bus Gen 1 1 30 Sec Equation 364 s Measured frequency slip across the CB to be synchronized fGen Measured generator side frequency fBus Measured bus side frequency Reset of frequency raise and lower command pulses The generated frequency raise and lower command pulses RAISE_F and LOWER_F are immediately reset if any of the following conditions is met During matching of its own CB synchroniz...

Page 1578: ...MATCH_PRO is active while the matching is in progress NTWMATCH_OK and NTWMATCH_PRO are available in the Monitored data view Frequency rate of change tuning When the control command parameter Tune V and F match is set to Freq match rate the function calculates the generator frequency matching rate dF dt The calculated frequency matching rate is stored to the nonvolatile memory output FREQ_CHG_RTE a...

Page 1579: ...of V F during network breaker synchronization In this application example breaker NSCB2 must be closed so the synchronizing conditions between the Bus1 and Bus2 power systems are checked by the autosynchronizer for network breaker function ASNSCSYN If the synchro check conditions are not met then ASNSCSYN sends the auto synchronization request and voltage and frequency difference ΔU ΔF between Bus...

Page 1580: ...r by clock number 30º This is called angle difference adjustment and can be set for ASGCSYN with the Phase shift setting 9 6 7 Signals 9 6 7 1 ASGCSYN Input signals Table 1519 ASGCSYN Input signals Name Type Default Description U3P1 SIGNAL Three phase voltages generator side U3P2 SIGNAL Three phase voltages bus side BLOCK BOOLEAN 0 False Blocking signal of the auto synchronization function CL_COMM...

Page 1581: ... 000 Network breaker fre quency difference from ASCGAPC1 ASC1_GEN_DAT INT32 0 Integer weighted in put data from ASC GAPC1 9 6 7 2 ASGCSYN Output signals Table 1520 ASGCSYN Output signals Name Type Description SYNC_INPRO BOOLEAN Auto synchronization in pro gress SYNC_OK BOOLEAN Systems in synchronism MATCH_INPRO BOOLEAN Voltage and frequency matching in progress MATCH_OK BOOLEAN Voltage and frequen...

Page 1582: ...d B G Any 2 Live G Dead B 1 Off Live dead mode Freq Diff Ov Synch 0 000 0 060 xFn 0 001 0 004 Over synchronous limit for admissible paralleling range Freq Diff sub Synch 0 000 0 060 xFn 0 001 0 004 Sub synchronous limit for admissible paralleling range Coarse Freq Diff Ov 0 000 0 060 xFn 0 001 0 005 Over synchronous limit during gener ator coarse match ing Coarse Freq Diff sub 0 000 0 060 xFn 0 00...

Page 1583: ...onous 2 Both direction 2 Both direction Synchronization di rection Voltage offset 0 100 0 100 xUn 0 001 0 000 Voltage offset Frequency offset 0 010 0 010 xFn 0 001 0 000 Frequency offset Table 1523 ASGCSYN Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Synchrocheck mode 1 Off 3 Asynchronous 4 Command 3 Asynchronous Synchroch...

Page 1584: ...uration Freq pulse off Intv 1000 120000 ms 10 20000 Set frequency pulse off interval time Freq pulse Min Dur 50 2000 ms 10 50 Set frequency pulse minimum duration 9 6 9 ASGCSYN Monitored data Table 1525 ASGCSYN Monitored data Name Type Values Range Unit Description ENERG_STATE Enum 0 Unknown 1 Both Live 2 Live G Dead B 3 Dead G Live B 4 Both Dead Energization state of bus and generator U_DIFF_MEAS...

Page 1585: ...tching voltage rate of change FREQ_CHG_RTE FLOAT32 0 000 0 050 xFn s Calculated generator matching frequency rate of change U_DIFF_NTW FLOAT32 3 00 3 00 xUn Voltage amplitude dif ference of the network breaker FR_DIFF_NTW FLOAT32 1 500 1 500 xFn Voltage frequency dif ference of the network breaker NTWMATCH_PRO BOOLEAN 0 False 1 True Matching in progress for network breaker synchronization NTWMATCH...

Page 1586: ...t pulse width 1 0 of the set value or 20 ms Energizing time for dead bus closing 1 0 of the set value or 35 ms Minimum Syn time for SYNC_OK 1 0 of the set value or 60 ms Reset time Typically 20 ms Closing angle accuracy 1 9 7 Autosynchronizer for network breaker ASNSCSYN ANSI 25AUTOSYNCBT T 9 7 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 ...

Page 1587: ...sued after considering the function modes essential checks CB closing time and the paralleling conditions In case of asynchronous systems the function initiates the matching of voltage and frequency with the help of available generators through Autosynchronizer co ordinator ASCGAPC The function contains a blocking functionality It is possible to block function outputs 9 7 4 Analog input configurat...

Page 1588: ...tion can work if two voltage channels along with the residual voltage from the Bus B side are connected to U3P1 and one voltage channel from the Bus A side is connected to channel 1 of U3P2 Dissimilar VT connection set tings for UTVTR on the Bus A and Bus B sides The function requires that all three voltage channels or two voltage channels along with the residual voltage are connec ted to either U...

Page 1589: ... 7 5 1 Energizing check The Energizing check module checks the energizing direction Energizing is the situation where a dead network part is connected to an energized section of the network The Live dead mode setting is used to set the energized condition of the bus section across the CB that is whether the bus section across the CB is live or dead When the Live dead mode setting parameter is set ...

Page 1590: ...itted This time delay ensures that the dead side remains de energized and that the situation is not caused by a temporary interference If the conditions do not persist for a specified operation time the timer is reset and the procedure is restarted when the conditions allow it The CB does not close if the measured voltage on the live side is greater than the set value of Max energizing V The measu...

Page 1591: ... diagram for Synchronization check and control Synchro check The function measures the voltage difference U_DIFF_MEAS frequency difference FR_DIFF_MEAS and phase angle difference PH_DIFF_MEAS between the two bus sides U DIFF MEAS U U Voltage offset BusA BusB _ _ Equation 366 UBusA Measured bus A side voltage UBusB Measured bus B side voltage Voltage off set Setting Voltage offset FR DIFF MEAS f f ...

Page 1592: ...inal frequency fn The measured bus A and bus B voltages are lower than the set value of Max energizing V When the Synchrocheck mode setting parameter is set to Command then the Synchronous Asynchronous or Off condition of the network across the CB can be set using the SynchroChk Mod Ctl control command only If the Synchrocheck mode setting parameter is not set to Command then the Synchrocheck mode...

Page 1593: ...d on the basis of the measured frequency and phase difference Depending on the CB and the closing system the delay between the closing signal and the CB closing is about 50 250 ms The selected Closing time of CB informs the function how long the conditions have to persist The value covers both the CB closing delay and the output type dependent delay The synchro check function compensates for the m...

Page 1594: ...in Table 1530 and thus synchronism is prevented the monitored data U_DIFF_SYNC is activated Similarly PH_DIF_SYNC and FR_DIFF_SYNC are activated based on the measurements PH_DIFF_MEAS and FR_DIFF_MEAS respectively These monitored data values are updated only when the setting Synchrocheck mode is set to either Synchronous or Asynchronous and the measured ENERG_STATE is Both Live The outputs U_DIFF ...

Page 1595: ... in the monitored data CB_CL_BLKD Table 1532 CB_CL_BLKD status based on the inputs IED test mode Inputs Monitored data CB_TEST EXT_CHECK CB_CL_BLKD TRUE TRUE TRUE 1 Unblocked FALSE FALSE TRUE TRUE FALSE 2 Ext Check Fail FALSE FALSE TRUE FALSE N A 3 IED Test CB Serv ice FALSE TRUE N A 4 IED Service CB Test ASNSCSYN can be set to the bypass mode by setting the parameters Synchrocheck mode and Live d...

Page 1596: ... to be activated If the setting Auto Syn mode is set as Automatic synchronising mode no additional command is required to activate the closing signal CLOSE_CB In this auto synchronization mode once all the closing conditions are satisfied within the set Maximum Syn time the outputs SYNC_OK and CLOSE_CB become TRUE and remain active as long as the closing conditions are fulfilled If Multiple comman...

Page 1597: ...ze CB is in progress and it is reset when the close command is reset or Maximum Syn time has elapsed In this automatic mode the closing signal CLOSE_CB is activated automatically once all the closing conditions are satisfied If the closing conditions are fulfilled during a permitted check time set with Maximum Syn time ASNSCSYN gives synchro check permission to the circuit breaker control CBXCBR a...

Page 1598: ...during Maximum Syn time starting from the moment the close command is activated The close command must be active while the closing conditions are fulfilled otherwise the procedure is cancelled If the closing conditions are fulfilled during Maximum Syn time a closing pulse output is delivered to the CB If the closing conditions are not fulfilled during the checking time the alarm CL_FAIL_AL is acti...

Page 1599: ...It checks for the synchronization conditions across the CB and releases the CB closing command If these conditions are not fulfilled the sources in the power network connected across this bus coupler or tie feeder CB have to change their operating points to meet the requirements This is achieved with Autosynchronizer co ordinator ASCGAPC available with the source ASGCSYN function and non source AS...

Page 1600: ...unction of source 1 ASGCSYN function It also sends the permission to the source to start matching the voltage and frequency The matching process is carried out so that the voltage and frequency difference between Bus1 and Bus2 measured by ASNSCSYN reduces and comes within the synchro check limits This satisfies the synchro check conditions for breaker NSCB2 which can then be synchronized by ASNSCS...

Page 1601: ... has to be developed outside the function block Voltage angle difference adjustment In applications where the power transformer is located between the voltage measurement and the CB the vector group connection gives phase difference to the voltages between the high and low voltage sides The angle adjustment can be used to meet synchronism The vector group of the power transformer is defined with c...

Page 1602: ...PEN BOOLEAN 0 False Circuit breaker open status CB_CLOSE BOOLEAN 0 False Circuit breaker close status ISO_A1_CLOSE BOOLEAN 0 False Isolator A1 close sta tus ISO_B1_CLOSE BOOLEAN 0 False Isolator B1 close sta tus ISO_A2_CLOSE BOOLEAN 0 False Isolator A2 close sta tus ISO_B2_CLOSE BOOLEAN 0 False Isolator B2 close sta tus ASC1_NS_DAT INT32 0 Coded integer data from ASCGAPC1 9 7 7 2 ASNSCSYN Output s...

Page 1603: ... Settings Table 1535 ASNSCSYN Group settings Basic Parameter Values Range Unit Step Default Description Live dead mode 2 Command 1 Off 1 Both Dead 2 Live B Dead A 3 Dead B Live A 4 Dead A B Any 5 Dead B A Any 6 One Live Dead 7 Not Both Live 1 Both Dead Live dead mode Diff voltage 0 01 0 50 xUn 0 01 0 05 Maximum voltage difference limit Diff frequency 0 001 0 060 xFn 0 001 0 001 Maximum frequen cy ...

Page 1604: ...YN Non group settings Advanced Parameter Values Range Unit Step Default Description Phase shift 180 180 deg 1 0 Phase difference correction between bus A and bus B voltages Minimum Syn time 0 60000 ms 10 0 Minimum time to accept synchroniz ing Maximum Syn time 100 6000000 ms 10 60000 Maximum time to accept synchroniz ing Energizing time 100 60000 ms 10 100 Time delay for en ergizing check Closing ...

Page 1605: ...of limit for synchro nizing PH_DIF_SYNC BOOLEAN 0 False 1 True Phase angle difference out of limit for synchro nizing SLIP_ACCL FLOAT32 0 000 5 000 xFn s Calculated rate of change of frequency slip ACT_ASC_CB INT32 0 2147483647 Active ASCGAPC host circuit breaker number CB_CL_BLKD Enum 1 Unblocked 2 Ext Check Fail 3 IED Test CB Service 4 IED Service CB Test CB close blocked status SYNCCHK_STS Enum...

Page 1606: ... Frequency difference 10 mHz Phase angle difference 1 Operation accuracy MATCH_OK for voltage 0 001 Un MATCH_OK for frequency 10 mHz Operation time accuracy Energizing time for dead bus closing 1 0 of the set value or 35 ms Minimum Syn time for SYNC_OK 1 0 of the set value or 60 ms Reset time Typically 20 ms Closing angle accuracy 1 Control functions 1MRS759142 F 1606 REX640 Technical Manual ...

Page 1607: ...5AUTOSYNC 9 8 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Autosynchronizer co ordinator ASCGAPC AUTOSYNC 25AUTOSYNC 1MRS759142 F Control functions REX640 Technical Manual 1607 ...

Page 1608: ... with the bus coupler or grid transformer autosynchronization functions ASNSCSYN as well as in generator autosynchronization functions ASGCSYN ASCGAPC performs the network topology determination to identify the subnetworks within the whole network It routes the voltage and frequency difference values from the synchronizing CB to all the generator sources It also identifies the sources which are el...

Page 1609: ...ASC_DAT U_DIFF_1 FR_DIFF_1 U_DIFF_17 FR_DIFF_17 ASC_SRC8_DAT Coordinator BLOCK ASC_NS2_DAT ASC_NS2_DAT Figure 883 Functional module diagram 9 8 4 1 Topology determination This module identifies the group of busbars power sources and network circuit breakers electrically connected together and calculates the subnetwork number for each group It also identifies the sources and buses which are electri...

Page 1610: ...ferent busbar arrangement across any non source CB The general busbar arrangement across any SCB is shown in Figure 885 For each source CB the Bus A and Bus B numbers are to be set These bus numbers for source CB 1 are set in Src1 bus A Num and Src1 bus B Num respectively Each of these settings can be set to values Bus 1 Bus 15 or to Not Configured Bus A Source CB Bus B Source Bus A Source CB Sing...

Page 1611: ...d in Figure 886 The first comprises Bus 1 Bus 2 NSCB 1 NSCB 2 SCB 2 and source 2 The second comprises Bus 3 Bus 4 NSCB 4 SCB 3 and source 3 Each network group is assigned a subnetwork number which is the lowest bus bar number in the subgroup Hence the first group is assigned subnetwork number 1 and the second group is assigned subnetwork number 3 Source 1 Bus 3 SCB 2 NSCB 1 NSCB 2 NSCB 3 SCB 1 SCB...

Page 1612: ... Num Bus 1 Non source CB1 connected bus A1 number NonSrc1 bus A2 Num Grid Non source CB1 connected bus A2 number NonSrc2 bus A1 Num Bus 1 Non source CB2 connected bus A1 number NonSrc2 bus A2 Num Bus 2 Non source CB2 connected bus A2 number NonSrc3 bus A1 Num Bus 2 Non source CB3 connected bus A1 number Table 1543 Settings of ASCGAPC of NSCB3 for given example Settings Suggested values Description...

Page 1613: ...us 4 Non source CB4 connected bus A2 number Table 1545 Settings of ASCGAPC of SCB1 for given example Settings Suggested values Description ASC CB Num1 Source CB 1 ASC1 host circuit breaker number 1 Number of sources 3 Total number of sources present in system Number of NonSrc CB 4 Number of bus coupler or grid transformer CB in the system Table 1546 Settings of ASCGAPC of SCB2 for given example Se...

Page 1614: ... CB is uncertain the group including this CB or the groups connected across this CB are assigned zero as the subnetwork number For example if the SCB1 status is uncertain then source 1 source 3 SCB1 SCB3 NSCB4 Bus 3 and Bus 4 are assigned zero as subnetwork number All subnetwork numbers are displayed as zero when ASC CB Num1 Sourcex x 1 8 9 8 4 2 Coordinator Three instances of ASNSCSYN can be conf...

Page 1615: ...B 1 NSCB 17 When the coordinator is active and NSCB 1 is selected for synchronization the corresponding voltage and frequency difference inputs U_DIFF_1 and FR_DIFF_1 are available as outputs U_DIFF and FR_DIFF respectively with their sign adjusted according to the setting NonSrc1 VT Conn If set as No Change the sign of U_DIFF and FR_DIFF remains the same If set as Reverse the sign is reversed Sim...

Page 1616: ... All the sources which are unavailable for participation are electrically connected to the grid or are not part of either subnetwork which must be synchronized by the selected CB Group 2 The sources which do not belong to Group 1 and are part of the subnetwork which includes the lower number busbar of the two busbars connected across the selected CB Group 3 The sources which do not belong to Group...

Page 1617: ... Group 3 5 Wrong source selection The synchronization request is received the command pa rameter Confirm source Sel is FALSE and the nominated sources do not belong to Group 2 or all belong to Group 3 6 Wrong tuning Src Sel The source selected for fine tuning is not among the nomina ted sources 8 Source ready Any of the selected sources are ready for matching 9 GOV AVR modes not OK Any source is s...

Page 1618: ... CB2 CB1 G1 Bus1 Bus2 Bus3 Bus4 Figure 888 Example of an internally connected network Externally connected A network where both Bus3 and Bus4 are connected to the grid across CB1 is considered an externally connected network CB2 CB1 Bus1 Bus2 TX1 TX2 Bus3 Bus4 Figure 889 Example of an externally connected network The number of sources active in the voltage and frequency matching is shared to sourc...

Page 1619: ...ization any NSCB communicates with ASCGAPC for matching of voltage and frequency difference ASCGAPC passes the required information to the participating sources along with their active status An NSCB synchronization is described with one typical example in Figure 890 Source 2 ASNSCSYN NSCB2 ASCGAPC ASGCSYN SCB2 ASGCSYN SCB1 ΔU ΔF Synchronize Start Matching Bus1 Bus2 Source 1 ASNSCSYN NSCB3 ASCGAPC...

Page 1620: ... Input data from source number 7 SRC8_ASC_DAT INT32 0 Input data from source number 8 NS1_ASC_DAT INT32 0 Input data from non source CB number 1 NS2_ASC_DAT INT32 0 Input data from non source CB number 2 NS3_ASC_DAT INT32 0 Input data from non source CB number 3 NS4_ASC_DAT INT32 0 Input data from non source CB number 4 NS5_ASC_DAT INT32 0 Input data from non source CB number 5 NS6_ASC_DAT INT32 0...

Page 1621: ... U_DIFF_2 FLOAT32 0 00 Voltage difference from non source CB 2 U_DIFF_3 FLOAT32 0 00 Voltage difference from non source CB 3 U_DIFF_4 FLOAT32 0 00 Voltage difference from non source CB 4 U_DIFF_5 FLOAT32 0 00 Voltage difference from non source CB 5 U_DIFF_6 FLOAT32 0 00 Voltage difference from non source CB 6 U_DIFF_7 FLOAT32 0 00 Voltage difference from non source CB 7 U_DIFF_8 FLOAT32 0 00 Volta...

Page 1622: ...FF_4 FLOAT32 0 000 Frequency difference from non source CB 4 FR_DIFF_5 FLOAT32 0 000 Frequency difference from non source CB 5 FR_DIFF_6 FLOAT32 0 000 Frequency difference from non source CB 6 FR_DIFF_7 FLOAT32 0 000 Frequency difference from non source CB 7 FR_DIFF_8 FLOAT32 0 000 Frequency difference from non source CB 8 FR_DIFF_9 FLOAT32 0 000 Frequency difference from non source CB 9 FR_DIFF_1...

Page 1623: ...ronizing CB FR_DIFF FLOAT32 Frequency difference across the synchronizing CB ASC_NS1_DAT INT32 Output data to non source CB 1 ASC_NS2_DAT INT32 Output data to non source CB 2 ASC_NS3_DAT INT32 Output data to non source CB 3 ASC_SRC1_DAT INT32 Output data to source num ber 1 ASC_SRC2_DAT INT32 Output data to source num ber 2 ASC_SRC3_DAT INT32 Output data to source num ber 3 ASC_SRC4_DAT INT32 Outp...

Page 1624: ... 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 0 Not Configured Source 1 CB con nected bus A num ber Src1 bus B Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 0 Not Configured Source 1 CB con nected bus B num...

Page 1625: ...3 14 Bus 14 15 Bus 15 0 Not Configured Source 2 CB con nected bus B num ber Src3 bus A Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 0 Not Configured Source 3 CB con nected bus A num ber Src3 bus B Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 0 Not Configured Source 3 CB con nected bu...

Page 1626: ... 14 15 Bus 15 0 Not Configured Source 4 CB con nected bus A num ber Src4 bus B Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 0 Not Configured Source 4 CB con nected bus B num ber Src5 bus A Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 0 Not Configured Source 5 CB con nected bu...

Page 1627: ...us 15 0 Not Configured Source 5 CB con nected bus B num ber Src6 bus A Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 0 Not Configured Source 6 CB con nected bus A num ber Src6 bus B Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 0 Not Configured Source 6 CB con nected bu...

Page 1628: ...Not Configured Source 7 CB con nected bus A num ber Src7 bus B Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 0 Not Configured Source 7 CB con nected bus B num ber Src8 bus A Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 0 Not Configured Source 8 CB con nected bu...

Page 1629: ... Source 8 CB con nected bus B num ber NonSrc1 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB1 connected bus A1 number NonSrc1 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 0 Not Configured Non source CB1 connec...

Page 1630: ... 0 Not Configured Non source CB1 connected bus B1 number NonSrc1 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB1 connected bus B2 number NonSrc2 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 0 Not Configured Non source CB2 con...

Page 1631: ...5 Bus 15 21 Grid 0 Not Configured Non source CB2 connected bus A2 number NonSrc2 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB2 connected bus B1 number NonSrc2 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 0 Not Configured Non source CB2 con...

Page 1632: ...s 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB3 connected bus A1 number NonSrc3 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB3 connected bus A2 number NonSrc3 bus B1 Num 0 Not Configured 1 Bus 1 0 Not Configured Non source CB3 con...

Page 1633: ... Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB3 connected bus B2 number NonSrc4 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB4 connected bus A1 number Table continues on th...

Page 1634: ...onfigured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB4 connected bus B1 number NonSrc4 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 0 Not Configured Non source CB4 conn...

Page 1635: ... bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB5 connected bus A2 number NonSrc5 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 0 Not Configured Non source CB5 conne...

Page 1636: ...us B2 number NonSrc6 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB6 connected bus A1 number NonSrc6 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 0 Not Configured Non source CB6 conne...

Page 1637: ...rce CB6 connected bus B1 number NonSrc6 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB6 connected bus B2 number NonSrc7 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 0 Not Configured Non source CB7 conn...

Page 1638: ...onfigured Non source CB7 connected bus A2 number NonSrc7 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB7 connected bus B1 number NonSrc7 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 0 Not Configured Non source CB7 con...

Page 1639: ... 21 Grid 0 Not Configured Non source CB8 connected bus A1 number NonSrc8 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB8 connected bus A2 number NonSrc8 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 0 Not Configured Non source CB8 con...

Page 1640: ...Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB8 connected bus B2 number NonSrc9 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB9 connected bus A1 number NonSrc9 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 0 Not Configured Non source CB9 con...

Page 1641: ... 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB9 connected bus B1 number NonSrc9 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB9 connected bus B2 number Table continues on the ne...

Page 1642: ...onfigured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB10 connected bus A2 number NonSrc10 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 0 Not Configured Non source CB10 c...

Page 1643: ... bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB11 connected bus A1 number NonSrc11 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 0 Not Configured Non source CB11 co...

Page 1644: ...s B1 number NonSrc11 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB11 connected bus B2 number NonSrc12 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 0 Not Configured Non source CB12 co...

Page 1645: ...e CB12 connected bus A2 number NonSrc12 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB12 connected bus B1 number NonSrc12 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 0 Not Configured Non source CB12 c...

Page 1646: ...figured Non source CB13 connected bus A1 number NonSrc13 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB13 connected bus A2 number NonSrc13 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 0 Not Configured Non source CB13 ...

Page 1647: ...1 Grid 0 Not Configured Non source CB13 connected bus B2 number NonSrc14 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB14 connected bus A1 number NonSrc14 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 0 Not Configured Non source CB14 ...

Page 1648: ...s 14 15 Bus 15 21 Grid 0 Not Configured Non source CB14 connected bus B1 number NonSrc14 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB14 connected bus B2 number NonSrc15 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 0 Not Configured Non source CB15 ...

Page 1649: ...7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB15 connected bus A2 number NonSrc15 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB15 connected bus B1 number Table continues on the ...

Page 1650: ...onfigured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB16 connected bus A1 number NonSrc16 bus A2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 0 Not Configured Non source CB16 c...

Page 1651: ... bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB16 connected bus B2 number NonSrc17 bus A1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 0 Not Configured Non source CB17 co...

Page 1652: ...s A2 number NonSrc17 bus B1 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 11 Bus 11 12 Bus 12 13 Bus 13 14 Bus 14 15 Bus 15 21 Grid 0 Not Configured Non source CB17 connected bus B1 number NonSrc17 bus B2 Num 0 Not Configured 1 Bus 1 2 Bus 2 3 Bus 3 4 Bus 4 5 Bus 5 6 Bus 6 7 Bus 7 8 Bus 8 9 Bus 9 10 Bus 10 0 Not Configured Non source CB17 co...

Page 1653: ...No Change Voltage transform er connection type for non source CB8 NonSrc9 VT Conn 2 No Change 3 Reverse 2 No Change Voltage transform er connection type for non source CB9 NonSrc10 VT Conn 2 No Change 3 Reverse 2 No Change Voltage transform er connection type for non source CB10 NonSrc11 VT Conn 2 No Change 3 Reverse 2 No Change Voltage transform er connection type for non source CB11 NonSrc12 VT ...

Page 1654: ...n source CB 15 16 Non source CB 16 17 Non source CB 17 18 Source CB 1 19 Source CB 2 20 Source CB 3 21 Source CB 4 22 Source CB 5 23 Source CB 6 24 Source CB 7 25 Source CB 8 1 Non source CB 1 ASC host circuit breaker number 1 ASC CB Num2 0 Not Configured 1 Non source CB 1 2 Non source CB 2 3 Non source CB 3 4 Non source CB 4 5 Non source CB 5 6 Non source CB 6 7 Non source CB 7 8 Non source CB 8 ...

Page 1655: ...B 12 13 Non source CB 13 14 Non source CB 14 15 Non source CB 15 16 Non source CB 16 17 Non source CB 17 0 Not Configured ASC host circuit breaker number 3 Table 1556 ASCGAPC Non group settings Advanced Parameter Values Range Unit Step Default Description Max matching time 100 6000000 ms 1 60000 Maximum time to complete the volt age and frequency matching Central PMS present 1 No 2 Yes 1 No Centra...

Page 1656: ...6 sub network number SBNW_NSCB7 INT32 0 99 Non source CB 7 sub network number SBNW_NSCB8 INT32 0 99 Non source CB 8 sub network number SBNW_NSCB9 INT32 0 99 Non source CB 9 sub network number SBNW_NSCB10 INT32 0 99 Non source CB 10 sub network number SBNW_NSCB11 INT32 0 99 Non source CB 11 sub network number SBNW_NSCB12 INT32 0 99 Non source CB 12 sub network number SBNW_NSCB13 INT32 0 99 Non sour...

Page 1657: ...nnec tion status SRC3_GRI_CON BOOLEAN 0 False 1 True Source 3 grid connec tion status SRC4_GRI_CON BOOLEAN 0 False 1 True Source 4 grid connec tion status SRC5_GRI_CON BOOLEAN 0 False 1 True Source 5 grid connec tion status SRC6_GRI_CON BOOLEAN 0 False 1 True Source 6 grid connec tion status SRC7_GRI_CON BOOLEAN 0 False 1 True Source 7 grid connec tion status SRC8_GRI_CON BOOLEAN 0 False 1 True So...

Page 1658: ... Group 3 4 Group 4 5 Group 5 6 Group 6 7 Group 7 8 Group 8 9 Group 9 Source 2 participation group SRC3_PTC_GRP Enum 1 Group 1 2 Group 2 3 Group 3 4 Group 4 5 Group 5 6 Group 6 7 Group 7 8 Group 8 9 Group 9 Source 3 participation group SRC4_PTC_GRP Enum 1 Group 1 2 Group 2 3 Group 3 4 Group 4 5 Group 5 6 Group 6 7 Group 7 8 Group 8 9 Group 9 Source 4 participation group SRC5_PTC_GRP Enum 1 Group 1 ...

Page 1659: ...oup 3 4 Group 4 5 Group 5 6 Group 6 7 Group 7 8 Group 8 9 Group 9 Source 8 participation group SELECTED_GRP Enum 1 Group 1 2 Group 2 3 Group 3 Selected source partici pation group CONFL_STATUS Enum 1 No conflict 2 Multiple NSCB sync 3 Multiple SCB sync 4 NSCB and SCB sync Autosynchronization conflict status NSCB_SYN_MOD Enum 0 Invalid 1 AS Man Relay Loc 2 AS Man Relay Rem 3 AS Semi Relay Loc 4 AS ...

Page 1660: ...SRC4_SYN_MOD Enum 0 Invalid 1 AS Man Relay Loc 2 AS Man Relay Rem 3 AS Semi Relay Loc 4 AS Semi Relay Rem 5 AS Auto Relay Loc 6 AS Auto Relay Rem Synchronization opera tion mode of source 4 SRC5_SYN_MOD Enum 0 Invalid 1 AS Man Relay Loc 2 AS Man Relay Rem 3 AS Semi Relay Loc 4 AS Semi Relay Rem 5 AS Auto Relay Loc 6 AS Auto Relay Rem Synchronization opera tion mode of source 5 SRC6_SYN_MOD Enum 0 ...

Page 1661: ...OLEAN 0 False 1 True Source 3 participation status SRC4_PTC_ST BOOLEAN 0 False 1 True Source 4 participation status SRC5_PTC_ST BOOLEAN 0 False 1 True Source 5 participation status SRC6_PTC_ST BOOLEAN 0 False 1 True Source 6 participation status SRC7_PTC_ST BOOLEAN 0 False 1 True Source 7 participation status SRC8_PTC_ST BOOLEAN 0 False 1 True Source 8 participation status ASCGAPC Enum 1 on 2 bloc...

Page 1662: ...ve programmable autoreclosing shots which can perform one to five successive autoreclosings of desired type and duration for instance one high speed and one delayed autoreclosing When the reclosing is initiated with starting of the protection function the autoreclosing function can execute the final trip of the circuit breaker in a short operate time provided that the fault still persists when the...

Page 1663: ...kout long trip The UNSUC_RECL output is activated after a pre defined two minutes alarming earth fault 9 9 3 2 Zone coordination Zone coordination is used in the zone sequence between local protection units and downstream devices At the falling edge of the INC_SHOTP line the value of the shot pointer is increased by one unless a shot is in progress or the shot pointer already has the maximum value...

Page 1664: ...e The BLK_THERM signal does not affect the starting of the sequence When the reclose time has elapsed and the BLK_THERM input is active the shot is not ready until the BLK_THERM input deactivates Should the BLK_THERM input remain active longer than the time set by the setting Max Thm block time the AR function goes to lockout If the BLK_THERM input is activated when the auto wait timer is running ...

Page 1665: ...CLM_T BLK_THERM INC_SHOTP RECL_ON Shot initiation Reclose controller AR_ON READY ACTIVE Figure 893 Functional module diagram 9 9 4 1 Signal collection and delay logic When the protection trips the initiation of autoreclosing shots is in most applications executed with the INIT_1 6 inputs The DEL_INIT2 4 inputs are not used In some countries starting the protection stage is also used for the shot i...

Page 1666: ...hat is capable of delaying a start signal has four time delays The time delay is selected based on the shot pointer in the AR function For the first reclose attempt the first time delay is selected for the second attempt the second time delay and so on For the fourth and fifth attempts the time delays are the same Time delay settings for the DEL_INIT_2 signal Str 2 delay shot 1 Str 2 delay shot 2 ...

Page 1667: ...rt signal of a protection stage After a start delay the AR function opens the circuit breaker and an autoreclosing shot is initiated When the shot is initiated with the trip signal of the protection the protection function trips the circuit breaker and simultaneously initiates the autoreclosing shot If the circuit breaker is manually closed against the fault that is if SOTF is used the fourth time...

Page 1668: ...ime elapses Normally all trip and start signals are used to initiate an autoreclosing shot and trip the circuit breaker ACTIVE output indicates reclosing sequence in progress If any of the input signals INIT_X or DEL_INIT_X are used for blocking the corresponding bit in the Tripping line setting must be FALSE This is to ensure that the circuit breaker does not trip from that signal that is the sig...

Page 1669: ...d to CBB configuration are First Seventh reclose time Init signals CBB1 CBB7 Blk signals CBB1 CBB7 Shot number CBB1 CBB7 The reclose time defines the open and dead times that is the time between the OPEN_CB and the CLOSE_CB commands The Init signals CBBx setting defines the initiation signals The Blk signals CBBx setting defines the blocking signals that are related to the CBB rows in the matrix T...

Page 1670: ...poses If the INIT_5 line is active during a sequence start the reclose attempt is blocked and the AR function goes to lockout If more than one CBBs are started with the shot pointer the CBB with the smallest individual number is always selected For example if the INIT_2 and INIT_4 lines are active for the second shot that is the shot pointer is 2 CBB2 is started instead of CBB5 Even if the initiat...

Page 1671: ...re during the synchronism check When the circuit breaker does not close the automatic initiation is carried out if the circuit breaker does not close within the wait close time after issuing the reclose command Both the automatic initiation is allowed when synchronization fails or the circuit breaker does not close The Auto init parameter defines which INIT_X lines are activated in the auto initia...

Page 1672: ... circuit breaker closes normally and the reclaim time starts When the reclaim time has elapsed the sequence is concluded successful 9 9 4 3 Shot pointer controller The execution of a reclose sequence is controlled by a shot pointer It can be adjusted with the SHOT_PTR monitored data The shot pointer starts from an initial value 1 and determines according to the settings whether or not a certain sh...

Page 1673: ...tivated CBB defines the reclose time When the reclose time has elapsed the CLOSE_CB output is not activated until the following conditions are fulfilled The SYNC input must be TRUE if the particular CBB requires information about the synchronism All AR initiation inputs that are defined protection lines using the Control line setting are inactive The circuit breaker is open The circuit breaker is ...

Page 1674: ...on after elapsed discrimination time new shot begins 9 9 4 5 Sequence controller When the LOCKED output is active the AR function is in lockout This means that new sequences cannot be initialized because AR is insensitive to initiation commands It can be released from the lockout state in the following ways The function is reset through communication with the RecRs parameter The same functionality...

Page 1675: ...cations involving down stream fuses tripping and initiation of shot 1 should be fast instantaneous or short time delayed The tripping and initiation of shots 2 3 and definite tripping time should be delayed In this example two overcurrent elements PHLPTOC and PHIPTOC are used PHIPTOC is given an instantaneous characteristic and PHLPTOC is given a time delay The PROT_CRD output is activated if the ...

Page 1676: ...he CLOSE_CB output is active for the time set with the Close pulse time setting The CLOSE_CB output is deactivated also when the circuit breaker is detected to be closed that is when the CB_POS input changes from open state to closed state The Wait close time setting defines the time after the CLOSE_CB command activation during which the circuit breaker should be closed If the closing of circuit b...

Page 1677: ...limit setting defines the number of reclose attempts that are allowed during the time defined with the Frq Op counter time setting If the set value is reached within a pre defined period defined with the Frq Op counter time setting the AR function goes to lockout when a new shot begins provided that the counter is still above the set limit The lockout is released after the recovery time has elapse...

Page 1678: ...ptions in the power system service and brings the power back on line quickly and effortlessly The basic idea of the auto reclose function is simple In overhead lines where the possibility of self clearing faults is high the auto reclose function tries to restore the power by reclosing the breaker This is a method to get the power system back into normal operation by removing the transient or semi ...

Page 1679: ...ot The settings related to CBB configuration are First Seventh reclose time Init signals CBB1 CBB7 Blk signals CBB1 CBB7 Shot number CBB1 CBB7 The reclose time defines the open and dead times that is the time between the OPEN_CB and the CLOSE_CB commands The Init signals CBBx setting defines the initiation signals The Blk signals CBBx setting defines the blocking signals that are related to the CB...

Page 1680: ... used for blocking purposes If the INIT_5 line is active during a sequence start the reclose attempt is blocked and the AR function goes to lockout If more than one CBBs are started with the shot pointer the CBB with the smallest individual number is always selected For example if the INIT_2 and INIT_4 lines are active for the second shot that is the shot pointer is 2 CBB2 is started instead of CB...

Page 1681: ...re during the synchronism check When the circuit breaker does not close the automatic initiation is carried out if the circuit breaker does not close within the wait close time after issuing the reclose command Both the automatic initiation is allowed when synchronization fails or the circuit breaker does not close The Auto init parameter defines which INIT_X lines are activated in the auto initia...

Page 1682: ...nced flexibility allowing multiple and adaptive sequences Each CBB is identical The Shot number CBB_ setting defines at which point in the auto reclose sequence the CBB should be performed that is whether the particular CBB is going to be the first second third fourth or fifth shot During the initiation of a CBB the conditions of initiation and blocking are checked This is done for all CBBs simult...

Page 1683: ...UNSUC_RECL DEL_INIT _4 DEL_INIT _3 DEL_INIT _2 INIT _6 INIT _5 INIT _4 INIT _3 INIT _2 INIT _1 SYNC INC_SHOTP CB_READY CB_POS RECL_ON INHIBIT _RECL BLK _RCLM_T BLK _RECL_T BLK _THERM AR_ON READY Figure 908 Example connection between protection and autoreclosing functions in protection relay configuration It is possible to create several sequences for a configuration Autoreclose sequences for overc...

Page 1684: ...times for shot 1 and shot 2 are different but each protection function initiates the same sequence The CBB sequence is described in Table 1560 as follows Shot 1 CBB1 0 3s Shot 2 CBB2 15 0s INIT_1 I INIT_2 I INIT_3 Io Lockout Lockout Lockout Figure 910 Two shots with three initiation lines Table 1560 Settings for configuration example 1 Setting name Setting value Shot number CBB1 1 Init signals CBB...

Page 1685: ...ults The third shot which is the second shot in the autoreclose sequence initiated by I or Io is set as a delayed autoreclosing and executed after an unsuccessful high speed autoreclosing of a corresponding sequence Figure 911 Autoreclosing sequence with two shots with different shot settings according to initiation signal t HSAR Time delay of high speed autoreclosing here First reclose time t DAR...

Page 1686: ... signals CBB2 6 lines 2 and 3 2 4 6 Second reclose time 0 2s an example Shot number CBB3 2 Init signals CBB3 6 lines 2 and 3 2 4 6 Third reclose time 10 0s 9 9 6 4 Delayed initiation lines The auto reclose function consists of six individual auto reclose initiation lines INIT_1 INIT 6 and three delayed initiation lines DEL_INIT_2 DEL_INIT_3 DEL_INIT_4 DEL_INIT_2 and INIT_2 are connected together w...

Page 1687: ... 4 and 5 Optionally can also be used with SOTF 9 9 6 5 Shot initiation from protection start signal In it simplest all auto reclose shots are initiated by protection trips As a result all trip times in the sequence are the same This is why using protection trips may not be the optimal solution Using protection start signals instead of protection trips for initiating shots shortens the trip times E...

Page 1688: ...ept that after the second shot when the protection starts again Str 2 delay shot 3 elapses before the protection operate time and the final trip follows The total trip time is the protection start delay 0 10 seconds the time it takes to open the circuit breaker 9 9 6 6 Fast trip in Switch on to fault The Str _ delay shot 4 parameter delays can also be used to achieve a fast and accelerated trip wi...

Page 1689: ...tion blocking signal 2 DEL_INIT_3 BOOLEAN 0 False Delayed AR initializa tion blocking signal 3 DEL_INIT_4 BOOLEAN 0 False Delayed AR initializa tion blocking signal 4 BLK_RECL_T BOOLEAN 0 False Blocks and resets re close time BLK_RCLM_T BOOLEAN 0 False Blocks and resets re claim time BLK_THERM BOOLEAN 0 False Blocks and holds the reclose shot from the thermal overload CB_POS BOOLEAN 0 False Circui...

Page 1690: ...PROT_CRD BOOLEAN A signal for coordination be tween the AR and the protec tion UNSUC_RECL BOOLEAN Indicates an unsuccessful re closing sequence AR_ON BOOLEAN Autoreclosing allowed READY BOOLEAN Indicates that the AR is ready for a new sequence i e the CB_READY input equals TRUE ACTIVE BOOLEAN Reclosing sequence is in pro gress 9 9 8 DARREC Settings Table 1565 DARREC Non group settings Basic Parame...

Page 1691: ... reclose time 0 300000 ms 10 5000 Dead time for CBB5 Sixth reclose time 0 300000 ms 10 5000 Dead time for CBB6 Seventh reclose time 0 300000 ms 10 5000 Dead time for CBB7 Init signals CBB1 0 63 1 0 Initiation lines for CBB1 Init signals CBB2 0 63 1 0 Initiation lines for CBB2 Init signals CBB3 0 63 1 0 Initiation lines for CBB3 Init signals CBB4 0 63 1 0 Initiation lines for CBB4 Init signals CBB5...

Page 1692: ... 10000 Cutout time for protection coordi nation Dsr time shot 1 0 10000 ms 100 0 Discrimination time for first reclosing Dsr time shot 2 0 10000 ms 100 0 Discrimination time for second reclos ing Dsr time shot 3 0 10000 ms 100 0 Discrimination time for third reclosing Dsr time shot 4 0 10000 ms 100 0 Discrimination time for fourth reclosing Auto wait time 0 60000 ms 10 2000 Wait time for re closin...

Page 1693: ...0000 ms 10 0 Delay time for start3 2nd reclose Str 3 delay shot 3 0 300000 ms 10 0 Delay time for start3 3rd reclose Str 3 delay shot 4 0 300000 ms 10 0 Delay time for start3 4th reclose Str 4 delay shot 1 0 300000 ms 10 0 Delay time for start4 1st reclose Str 4 delay shot 2 0 300000 ms 10 0 Delay time for start4 2nd reclose Str 4 delay shot 3 0 300000 ms 10 0 Delay time for start4 3rd reclose Str...

Page 1694: ...in pro gress SUC_RECL BOOLEAN 0 False 1 True Indicates a successful reclosing sequence UNSUC_CB BOOLEAN 0 False 1 True Indicates an unsuccess ful CB closing CNT_SHOT1 INT32 0 2147483647 Resetable operation counter shot 1 CNT_SHOT2 INT32 0 2147483647 Resetable operation counter shot 2 CNT_SHOT3 INT32 0 2147483647 Resetable operation counter shot 3 CNT_SHOT4 INT32 0 2147483647 Resetable operation co...

Page 1695: ...tionality The tap changer control with voltage regulator function OL5ATCC on load tap changer controller regulates the voltage of power transformers with on load tap changers in distribution substations OL5ATCC provides manual or automatic voltage control of the power transformer by using the raising or lowering signals to the on load tap changer The automatic voltage regulation can be used in sin...

Page 1696: ...Please refer to Preprocessing function block section in this manual for possible signal sources There are few special conditions which must be noted with configuration See Table 1570 Table 1570 Special conditions Condition Note U3P1 or U3P2 connected to real measurements Function can work with one voltage connected to channel 1 or with two voltages connected to channels 2 and 3 or with all three v...

Page 1697: ...CAL LOWER_LOCAL CON_STATUS Parallel manual PARALLEL AUTO MSTR_TRIGG FLLW4_CTL FLLW5_CTL TR4_DAT TR5_DAT BLKD_I_LOD BLKD_U_UN RNBK_U_OV BLKD_I_CIR BLKD_LTCBLK TIMER_ON MASTER Manual voltage regulation Manual TAP_DIFF Reverse power flow handling REV_REG I3P2 I2A I2_B I2_C U3P2 U2_AB PWR_DIR Figure 915 Functional module diagram 9 10 5 1 Voltage and current measurements The measured voltage must be a ...

Page 1698: ...erage filtered by the same fixed length window The phase angle value can be read from the monitored data ANGL_UA_IA These currents and phase angle differences are used solely in circulating current calculations There are minimum limits for the voltage and current magnitudes so the magnitude and phase angle difference values diverge from zero The voltage magnitude must exceed three percent of Un an...

Page 1699: ... set to Input control the active operation mode is determined by the input MSTR_TRIGG When the Parallel mode setting is set to Command the active operation mode is determined by the IEC 61850 command data point MstrOp MSTR_TRIGG is a rising edge input that is the master role is kept even though the MSTR_TRIGG input changes from true to false This functionality is used because another parallel tran...

Page 1700: ...e operation mode change using three inputs PARALLEL AUTO MSTR_TRIGG and setting group change either by input or via menu is needed when the active operation mode must be changed automatically that is there is a logic which drives these three inputs based on the status information from the circuit breakers The common Local Remote L R exclusion concerns the manual raise and lower commands of OL5ATCC...

Page 1701: ...data FAIL_FLLW In parallel manual mode the TR_STATUS monitored data indicates Master status to the other parallel transformers Voltage control vs tap changer moving direction OL5ATCC has the control settings Lower block tap and Raise block tap which give the tap changer position that results in the lowest and highest controlled voltage value usually at the LV side of the transformer Raise block ta...

Page 1702: ...ge is met The purpose of the regulator is to maintain a stable voltage on the regulated side of the power transformer The basis for this operation is the Band center voltage setting By increasing or decreasing various compensation factors the regulator calculates a control voltage from the band center voltage as shown in Equation 373 Hence the control voltage is the desired transformer regulated s...

Page 1703: ...ap changer operation is not enough to regulate the transformer voltage within the hysteresis limits a second adjustable delay T2 Control delay time 2 usually with a shorter time setting than T1 starts This delay is used for the control commands within the same sequence until the recovery of voltage occurs The delays T1 and T2 can be selected either with definite or inverse time characteristics In ...

Page 1704: ...L RL UB UL Load Figure 917 Equivalent electrical circuit for calculating the LDC term The compensation parameters Line drop V Ris U r and Line drop V React Ux are percentage values of Un according to the equations Line dropV Ris U I R U Line dro r CT n VT n _ _ 3 100 1 1 Un p pV React U I X U U x CT n VT n n _ _ 3 100 1 1 Equation 374 I CT_n1 Nominal primary current of the CT U VT_n1 Nominal prima...

Page 1705: ...ltage levels in the feeder lines in such a case and lowering the voltage at the substation can have harmful effects in the far end of the network However the Rv Pwr flow allowed setting allows also negative LDC terms to be taken into equation The topology changes in the network can cause changes to the equivalent impedance value of the network If the change is substantial the setting groups can be...

Page 1706: ...inish the circulating current LDC equation and parallel connection The additional challenge in the parallel connection regarding LDC is to know the total current which flows through the parallel transformers In the Master Follower mode it is easier to know the total current than in other parallel modes since the transformers are assumed to have identical ratings that is the total current IL in Equ...

Page 1707: ...C TRx_DAT for proper M F functionality If TR_STATUS is left unconnected that particular parallel transformer is assumed to not be participating even though receiving valid tap position information To keep all the tap changers in the same position the master needs to know the tap positions of the followers This way the circulating current is kept at its minimum The position values of the followers ...

Page 1708: ...s different tap positions in the parallel transformers Moreover these modes allow different ratings and step voltages for the parallel transformers Therefore it is reasonable to apply the out of step function only to the M F operation mode In an out of step situation at startup follower commands take place only after the master has given its own control command which is echoed to the followers Thi...

Page 1709: ...hanger positions are identical the currents of the transformers are in the same phase as the total load current If the tap changer positions are different the circulating current flows and the currents of different transformers either lag or lead the load current Figure 918 shows that the circulating current is the reactive component which separates the measured current vector from the expected an...

Page 1710: ... be suppressed with the logic This kind of stepwise change can occur for example when a capacitor bank is switched on to compensate a reactive power flow Another possibility is to use an automatic setting group change between setting groups in different loading situations The setting groups then have different set values for the load phase angle Minimizing Circulating Current MCC The MCC principle...

Page 1711: ...tor 2 The circulating current can be read from the monitored data I_CIR Using the circulating current the compensation term Uci can be calculated with the equation U I I U ci ci CT n n _ 1 100 Stability factor Equation 379 Ici Circulating current ICT_n1 Nominal primary current of the CT Stability factor Stability setting the recommended value depends on the loop impedance The value of Uci which ca...

Page 1712: ...out the current phasor can be read from the monitored data TR0_I_AMPL and TR0_I_ANGL The allowed active operation modes for sending data are MCC or Manual both with the input CON_STATUS activated The communication is active when the sent and received phasor magnitude is not clamped to zero The communication phasor magnitude is zero due to a rejected active operation mode or too low signal magnitud...

Page 1713: ...tap then HV side voltage and current are calculated as 1 _ _ Equation 382 1 _ _ Equation 383 UHV HV side voltage which will be compared with control voltage Up for HV side regulation IHV HV side current UMV MV side measured voltage IMV MV side measured current TAP_NOM Tap nominal TAP_POS Own tap position ΔUstep Step of Tap ZV Impedance voltage referred to MV side When Bi dir calc set value is used...

Page 1714: ...nd T2 only either before T1 has started or after T2 has elapsed Table 1573 Different timer mode delays Timer mode Setting Description T1 Control delay time 1 First delay when the measured voltage exceeds or falls below the limit value T2 Control delay time 2 Second delay when the first control did not bring the measured voltage to a desired level The delay after the command pulse activation and th...

Page 1715: ...ng pulse is issued The UD_CTL monitored data can also be seen in the DT timer mode The hysteresis approach is presented in Figure 916 Figure 920 Inverse time characteristic for different values on T1 or T2 The smaller figure is a zoom in of the larger one 9 10 5 9 Pulse control The tap changer generates an active operating signal when the tap changing process is active This signal is used for alar...

Page 1716: ...cking scheme The operation of the voltage regulator can be blocked for several reasons The purpose of blocking is to prevent the tap changer from operating under conditions that can damage the tap changer or exceed other power system limits The BLK_STATUS monitored data does not imply actual blocking but reveals if the coming command pulse is issued or not The blocking itself happens when the corr...

Page 1717: ...ault value for the parameter is OC This means that the default blocking schema explained in Table 1575 operates as such However there are other alternatives that cause different operations Table 1576 Customized manual blocking schema Manual blocking type Enumeration Description 1 Custom disabled No load current block lower under voltage external block ing has no effect in the manual operation mode...

Page 1718: ...k lower voltage Runback raise voltage High circulatin g current External block Extreme positions Manual Parallel manual Raise x x Lower x Table 1578 Blocking schema for selection OC UV EXT Active operation mode Comman d Load current Block lower voltage Runback raise voltage High circulatin g current External block Extreme positions Manual Parallel manual Raise x x x x x Lower x x x x Table 1579 Bl...

Page 1719: ...tion can be found in Chapter 9 10 5 4 Manual voltage regulation This operation can be adjusted with the setting parameter Runback raise V The blocking status can be read from the output RNBK_U_OV High Circulating Current The circulating current value is calculated in the operation modes Negative Reactance Principle NRP and Minimizing Circulating Current MCC Only the automatic operation in these mo...

Page 1720: ...ult normal automatic operation mode is not possible before this happens Fast lowering control causes successive LOWER_OWN pulses to be activated The time between consecutive pulses is the pulse length plus 1 5 seconds There is no tap changer operating delay otherwise 6 seconds taken into account in this cycle meaning that some command pulses are ineffective due to tap changer operation as describe...

Page 1721: ...where the regulator has problems to bring the regulated voltage to a desired level To detect this OL5ATCC has a setting Max operations in 1h which defines the allowed number of lowering and raising commands during a one hour sliding time window The detection is active both in the manual and automatic operation modes The alarm is reset after the counted number of the operations during the one hour ...

Page 1722: ... BOOLEAN 0 False Lower command in put from configura tion CON_STATUS BOOLEAN 0 False Network connection status of the own transformer LTC_BLOCK BOOLEAN 0 False External signal for blocking TCO BOOLEAN 0 False Tap changer operat ing input RSV BOOLEAN 0 False Reduce set voltage active PWR_DIR Enum 1 forward Power flow direction 9 10 7 2 OL5ATCC Output signals Table 1581 OL5ATCC Output signals Name T...

Page 1723: ...r 5 in the Master Follower opera tion mode BLKD_I_LOD BOOLEAN Indication of over current blocking BLKD_U_UN BOOLEAN Indication of under voltage blocking RNBK_U_OV BOOLEAN Indication of raise voltage runback BLKD_I_CIR BOOLEAN Indication of high circulating current blocking BLKD_LTCBLK BOOLEAN Indication of external block ing ALARM BOOLEAN Alarm status PAR_FAIL BOOLEAN Parallel failure detected PAR...

Page 1724: ... 0 Reactive line drop compensation fac tor Band reduction 0 00 9 00 Un 0 01 0 00 Step size for reduce set voltage RSV Stability factor 0 0 70 0 0 1 0 0 Stability factor in parallel operation Load phase angle 89 89 deg 1 0 Load phase shift used only with the negative reactance principle Control delay time 1 1000 300000 ms 100 60000 Control delay time for the first control pulse Control delay time 2...

Page 1725: ...e blocked Runback raise V 0 80 2 40 xUn 0 01 1 25 Voltage limit where fast lower com mands takes place Cir current limit 0 10 5 00 xIn 0 01 0 15 Blocking limit for high circulating current LTC pulse time 500 10000 ms 100 1500 Output pulse dura tion common for raise and lower pul ses Regulation mode 1 Forward 2 Bi dir meas 3 Bi dir calc 4 Auto select 1 Forward Regulation mode Table 1585 OL5ATCC Non...

Page 1726: ... phase volt age average filtered ANGL_UA_IA FLOAT32 180 180 deg Measured angle value between phase A volt age and current TIMER_STS Enum 0 Timer off 1 Lower timer1 on 2 Raise timer1 on 3 Lower timer2 on 4 Raise timer2 on 5 Fast lower T on Timer T1 T2 or fast low er timer active OPR_MODE_STS Enum 0 Not in use 1 Manual 2 Auto single 3 Parallel manual 4 Auto master 5 Auto follower 6 MCC 7 NRP The act...

Page 1727: ...ur FAIL_FLLW Enum 0 No failed followers 1 T1 2 T2 3 T1 T2 4 T3 5 T1 T3 6 T2 T3 7 T1 T2 T3 8 T4 9 T1 T4 10 T2 T4 11 T1 T2 T4 12 T3 T4 13 T1 T3 T4 14 T2 T3 T4 15 T1 T2 T3 T4 16 T5 17 T1 T5 18 T2 T5 19 T1 T2 T5 20 T3 T5 21 T1 T3 T5 22 T2 T3 T5 23 T1 T2 T3 T5 24 T4 T5 25 T1 T4 T5 26 T2 T4 T5 27 T1 T2 T4 T5 28 T3 T4 T5 29 T1 T3 T4 T5 30 T2 T3 T4 T5 31 T1 T2 T3 T4 T5 Failed followers PAR_UNIT_MCC Enum 0...

Page 1728: ...T4 T5 29 T1 T3 T4 T5 30 T2 T3 T4 T5 31 T1 T2 T3 T4 T5 OPR_CNT INT32 0 2147483647 Total number of raise and lower commands given in the manual and automatic modes TR0_I_AMPL FLOAT32 0 00 15000 00 A Transmitted current magnitude TR0_I_ANGL FLOAT32 180 00 180 00 deg Transmitted current an gle TR_STATUS Enum 0 Independent 1 Master 2 Follower Transformer status in formation OL5ATCC Enum 1 on 2 blocked ...

Page 1729: ...ically 0 80 1 20 Typically 0 96 1 04 9 10 11 Technical revision history Table 1588 OL5ATCC Technical revision history Product connectivity level Technical revision Change PCL2 B Added new output TAP_DIFF for indicating the difference in tap position between mas ter and follower Changed the Band width voltage minimum value to 1 00 Added setting Inst out of step Cor for en abling triggering of insta...

Page 1730: ...el resistor to increase the resistive earth fault current The controller can also manage an additional parallel fixed coil control PASANCR is intended for controlling arc suppression coils in networks with natural ground capacitance asymmetry for example mixed overhead line and cable networks The main features of the function are Operation based on forced change in zero sequence voltage Arc suppre...

Page 1731: ...Phase to phase voltage AB must be connected to the controller If only the phase voltages are measured the voltage U_AB is calculated internally in the protection relay Coil position The controller supports two possibilities for the coil position measurement Position Meas mode setting is used to select the active coil position measurement Available options are Pos indication Using only the RTD inpu...

Page 1732: ...ts The following outputs should be considered in order to ensure correct operation of the controller if a fixed parallel coil or parallel resistor is installed in the network FIXCOIL OP_FIXCOIL and CL_FIXCOIL Status signal and corresponding open and close command signals with 100 ms fixed pulse length for controlling the circuit breaker or disconnector of the fixed parallel coil These signals are ...

Page 1733: ...RM TUNING_SUC OP_FIXCOIL CL_FIXCOIL OP_RESISTOR CL_RESISTOR FIXCOIL TUNING_ACT EA EB EC IA IB IC COIL Optional 9 11 6 Operation principle The Operation setting is used to enable or disable the function The corresponding parameter values are on and off The operation of PASANCR can be described with a module diagram All the modules in the diagram are explained in the next sections 1MRS759142 F Contr...

Page 1734: ...n open delta connection of phase to earth voltage transformers Coil measurement is available from the arc suppression coil s measurement winding Position Meas mode setting is used to select the measurement between coil position indication and coil position indication with a CT or sensor Pos indication option uses the potentiometer based COIL_POS information only If Pos ind and meas option is selec...

Page 1735: ...ion between present zero sequence voltage and the reference voltage When TUNING_TRIGG value is below 100 the controller is at stand by When TUNING_TRIGG value is above 100 that is Uo vector in Figure 924 enters the red area the tuning delay is started Re U Im U Red area Trigger of tuning procedure Green area r dUo threshold No trigger U0 dUo threshold Figure 924 Phasor triggering mode Level detect...

Page 1736: ...g every 10 minutes V Ref adaptive delay setting V Ref adaptive delay Unnecessary tuning Tuning delay Uref V Res change level Figure 925 Example of Uo fluctuation with and without adaptive Uref feature amplitude triggering mode 9 11 6 3 Network parameter calculation To explain the controller the simplified equivalent circuit of a three phase distribution network illustrated in Figure 926 is used Th...

Page 1737: ...e A to earth voltage of the source E B Phase B to earth voltage of the source E C Phase C to earth voltage of the source U A Phase A to earth voltage at busbar EA Uo U B Phase B to earth voltage at busbar EB Uo U C Phase C to earth voltage at busbar EC Uo U 0 Zero sequence voltage UA UB UC 3 U 0coil Zero sequence voltage measured at coil I A Phase A current at the source I B Phase B current at the...

Page 1738: ...verted into equivalent current values by multiplying them by the system nominal phase to earth voltage Un Ief_network Bsymm Basymm Un Uncompensated earth fault current Iloss_network Gsymm Gasymm Un Network shunt losses Icoil Bcoil Un Coil inductive current Iloss_coil Gcoil Un Coil loss current Network parameter calculation is based on the forced change in network zero sequence voltage This is achi...

Page 1739: ...ge exceeds the V Res variation setting the controller can proceed immediately to network parameters calculation If the change defined in V Res variation setting cannot be obtained using resistor switching the controller automatically uses the coil movement method In the case of resistor switching the setting V Res maximum is ineffective After sufficient change in the measured zero sequence voltage...

Page 1740: ...t position 110A Figure 927 Damping of the resonance curve by using the parallel resistor The number of maximum tuning cycles can be limited with Tuning cycles setting The delay between consecutive tuning cycles is controllable by setting Tuning cycles delay After the maximum number of tuning cycles is reached the tuning procedure can be started by activating the ST_TUNING input for example via HMI...

Page 1741: ...espondingly for example disconnecting feeders to isolate the earth fault Tuning during EF can be performed when the measured zero sequence voltage is below 80 percent of the system s nominal phase to earth voltage If the measured zero sequence voltage is over 80 percent of the system s nominal phase to earth voltage the Blocked during EF mode is automatically switched into use Fixed parallel coil ...

Page 1742: ...t has stopped to V Res maximum position Tuned at low limit Number of cases when coil final position is limited either by low end position indication of the coil or the limited operating range Minimum current Tuned at high limit Number of cases when coil final position is limited either by high end position indication of the coil or the limited operating range Maximum current Earth faults Transient...

Page 1743: ...tting can be changed via the settings menu or HMI application 9 11 6 6 Resistor control Zero sequence currents in compensated networks are usually very low making it difficult to select the faulty line To avoid sensitivity problems the parallel resistor of the ASC is often used to increase the zero sequence current allowing a simple earth fault protection to locate the faulty line PASANCR contains...

Page 1744: ...rs the resistor is restored to healthy state at latest after one second from the last resistor change If the resistor already is in its healthy state when the earth fault recovers the status remains It is also possible to manually trigger the resistor control sequence with ST_RESIS_SEQ binary input 9 11 6 7 Blocking The BLK_AUTO input blocks the automatic operation of the function PASANCR s automa...

Page 1745: ...ed is determined during the calibration procedure Secondly the coil is moved to its middle position and the after running and mechanical play of the coil are determined Finally the potentiometer gaps are determined All results from coil calibration running speed after running mechanical play and potentiometer gap locations are visible in the Monitored data view After the calibration the coil linea...

Page 1746: ...the gaps is displayed on the HMI after the calibration Actual gap locations GAP_LO_VAL_x and GAP_HI_VAL_x x 1 5 which corresponds to the gap identification number are visible in the Monitored data view If the maximum number of five gap locations is exceeded the first pair is overwritten The coil position should be known and the controller operation should be guaranteed even if no new calibration i...

Page 1747: ...e coil movement as the coil position is based on a calculated estimate The purpose of the gap detection functionality is to enable the controller operation even if the potentiometer is worn out during the normal operation The potentiometer should be replaced during the next service break in order to guarantee accurate operation of the controller The gap detection functionality can be disabled by s...

Page 1748: ...signal triggers the au tomatic tuning proce dure ST_RESIS_SEQ BOOLEAN 0 False Rising edge of this signal triggers the resistor control se quence RAISE_LOCAL BOOLEAN 0 False Increase arc suppres sion coil current LOWER_LOCAL BOOLEAN 0 False Decrease arc sup pression coil current PARALLEL BOOLEAN 0 False Parallel controller has coil movement in pro gress BLK_AUTO BOOLEAN 0 False Blocking the coil au...

Page 1749: ...POT_ALARM BOOLEAN Potentiometer alarm EARTH_FAULT BOOLEAN Earth fault indication HIF BOOLEAN High impedance fault indica tion TUNING_ACT BOOLEAN Automatic tuning procedure ongoing TUNING_SUC BOOLEAN Tuning successful 9 11 10 PASANCR Settings Table 1594 PASANCR Group settings Basic Parameter Values Range Unit Step Default Description Compensation mode 1 Absolute 2 Relative 1 Absolute Compensation d...

Page 1750: ...nce volt age allowed during automatic tuning process Temporary damp ing 0 False 1 True 0 False Resistor switching on off allowed dur ing the automatic tuning procedure Minimum current 0 100 A 1 0 Minimum current of arc suppression coil low operating limit Maximum current 0 10000 A 1 10000 Maximum current of arc suppression coil high operating limit Error position 1 Current 2 Previous 3 Default 2 P...

Page 1751: ...aximum number of tuning cycles Tuning cycle delay 0 86400 s 1 300 Delay between con secutive tuning cy cles Table 1596 PASANCR Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on 5 off 1 on Operation Off On Coil V Nom 0 400000 V 1 10000 Adjustable arc sup pression coil nomi nal voltage Fix coil V Nom 0 400000 V 1 10000 Fixed arc suppres sion coil nominal vo...

Page 1752: ...l current 1 0 10000 A 1 0 Coil current 1 Pot value 2 0 3000 ohm 1 0 Potentiometer val ue 2 Coil current 2 0 10000 A 1 0 Coil current 2 Pot value 3 0 3000 ohm 1 0 Potentiometer val ue 3 Coil current 3 0 10000 A 1 0 Coil current 3 Pot value 4 0 3000 ohm 1 0 Potentiometer val ue 4 Coil current 4 0 10000 A 1 0 Coil current 4 Pot value 5 0 3000 ohm 1 0 Potentiometer val ue 5 Coil current 5 0 10000 A 1 ...

Page 1753: ...tersen coil detuning in amperes DETUNING_REL FLOAT32 100 00 100 00 Petersen coil detuning in percent UREF_AMPL FLOAT32 0 00 100 00 xUn Reference voltage am plitude UREF_ANG FLOAT32 180 00 180 00 deg Reference voltage angle URESO_AMPL FLOAT32 0 100000 V Resonance point volt age amplitude without the parallel resistor URESO_REL FLOAT32 0 0 100 0 Resonance point volt age in percent without the parall...

Page 1754: ...oing TUNING_ST_DELAY INT32 0 3600 s Remaining delay time in seconds to start auto matic tuning procedure OPR_TIME INT32 0 999999 h Controller time in oper ation hours CNT_TUNINGS INT32 0 999999 Counter of started tun ing procedures CNT_TUNED INT32 0 999999 Counter of successful tuning procedures CNT_CNL_TUN INT32 0 999999 Counter of cancelled tuning procedures CNT_TUN_UMAX INT32 0 999999 Counter o...

Page 1755: ...ltaneously indi cation from both end switches 5 Potentiometer maxi mum gap length excee ded 6 Potentiometer new gap appeared 7 Maximum number of potentiometer gaps ex ceeded 8 Check measurements 9 Umin not reached 10 Cannot obtain mini mum Uo variation Alarm status TUNING_STS Enum 1 Tuned successfully 2 Not tuned 3 Tuned at Umax 4 Tuned at low limit low end switch or low operating limit 5 Tuned at...

Page 1756: ...000 1000 000 mS Coil susceptance GCOIL FLOAT32 1000 000 1000 000 mS Coil conductance BFIXCOIL FLOAT32 1000 000 1000 000 mS Fixed parallel coil sus ceptance GFIXCOIL FLOAT32 1000 000 1000 000 mS Fixed parallel coil con ductance GPARALLEL FLOAT32 1000 000 1000 000 mS Parallel resistor conduc tance I_COIL_HMI FLOAT32 0 00 10000 00 A Coil current value dedi cated for HMI purposes depends on Resonance ...

Page 1757: ...omes inactive New output TUNING_SUC Tuned successfully New monitored data B_RATIO Network capacitive current I_C_NETWORK is scaled with respect to residual voltage channel setting Primary voltage IRES input allows connection from GRPOFF function block Outputs OP_RESISTOR CL_RESISTOR OP_FIXCOIL and CL_FIXCOIL are fixed to 100 ms pulses TUNING_STS enumerator has new elements 1 Network resonance poin...

Page 1758: ...C ANSI I O BT 9 12 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE identification High speed bus transfer HSABTC I O BT I O BT Control functions 1MRS759142 F 1758 REX640 Technical Manual ...

Page 1759: ...lternative standby supply for loads connected to a busbar thus minimizing disturbances for the primary process Electrical power supply stability and availability is most essential for many industrial processes Interruptions in the power supply can cause considerable production 1MRS759142 F Control functions REX640 Technical Manual 1759 ...

Page 1760: ...Voltage from busbar I3P1 Current from feeder 1 I3P2 Current from feeder 2 Recommended number of measured voltages is following U3P1 all three phases can be phase to phase or phase to ground voltages U3P2 all three phases can be phase to phase or phase to ground voltages U3P_BB one phase to phase voltage Minimum requirement is to have one voltage connected to each voltage group In this case all mea...

Page 1761: ...nnect full three phase current triplet to both I3P inputs Table 1602 Supported current connections I3P1 I3P2 Note All three phases connected All three phases connected Recommended Not connected Not connected Limited functionality 9 12 5 Operation principle The Operation setting is used to enable or disable the function When selected On the function is enabled and respectively Off means function is...

Page 1762: ...CB2 DISA_FBBM DISA_RUN OPR_LOADSHED RDYOPN_CB1 RDYCLS_CB1 RDYOPN_CB2 RDYCLS_CB2 DISA_CBOPN ENA_FASTONLY TRANSFER_ON Recorded data U_AB_1 U_BC_1 U_CA_1 U_AB_2 U_BC_2 U_CA_2 U_AB_BB FRQ_MEAS_1 FRQ_MEAS_2 FRQ_MEAS_BB ANG_DIFF INIT_UF INIT_UV INIT_EXT Evaluation Transfer direction Bus transfer Circuit breaker monitoring Load shedding Voltage monitoring Transfer initiation INIT_MAN INIT_CBOPN ACT_LKOUT...

Page 1763: ... feeder 1 U_AB_1 U_BC_1 U_CA_1 and feeder 2 U_AB_2 U_BC_2 U_CA_2 Frequency calculation This module calculates the frequencies of feeder 1 feeder 2 and busbar The calculated frequencies for feeder 1 feeder 2 and busbar FRQ_MEAS_1 FRQ_MEAS_2 and FRQ_MEAS_BB respectively are available as function outputs Angle calculation This module calculates phase angle difference between feeder 1 and busbar ANG_D...

Page 1764: ...en present direction of transfer is from feeder 1 to feeder 2 and stand by feeder is feeder 2 LAST_TR_1_2 output shows if the last valid transfer has been from feeder 1 to feeder 2 Direction 2 to 1 check Breaker position information for feeder 2 is obtained from POSOPN_CB2 and POSCLS_CB2 inputs Circuit breaker readiness to open and close are defined with inputs RDYCLS_CB1 and RDYOPN_CB2 If the CB2...

Page 1765: ...ion TR_1_2_OK TRUE Transfer direction TR_2_1_OK TRUE Figure 935 Example figure of breaker configuration 9 12 5 3 Evaluation Functionally module can be split to submodules presented in Figure 936 Each module is explained later below 1MRS759142 F Control functions REX640 Technical Manual 1765 ...

Page 1766: ...s activated The measured angle difference between stand by feeder and busbar ANG_DIFF is available as function output Same way frequency difference is determined between the voltage of busbar and the voltage of the stand by feeder If frequency difference is greater than setting Max frequency Diff output FRQ_DIFF_FAIL is activated The measured frequency difference FRQ_DIFF is shown in monitored dat...

Page 1767: ...rence is inside sector defined by Maximum phase lead and Maximum phase lag GRAD_FAIL is FALSE Frequency rate of change in busbar is less than setting Max DfDt BLOCK input is FALSE TRANSFER_ON input is TRUE DISA_INIT input is FALSE LOCKOUT is FALSE Function is not in lockout Transfer is allowed to one direction i e TR_1_2_OK or TR_2_1_OK is true If all conditions are met then the information is sig...

Page 1768: ... READY output is FALSE Function is set off or TRANSFER_ON is FALSE Off Function is set off or TRANSFER_ON is FALSE 9 12 5 4 Transfer initiation Functionally module can be split to submodules presented in Figure 937 Each module is explained later below Under frequency initiation Under voltage initiation External transfer initiation Circuit breaker open transfer initiation DISA_INIT INIT_TR_1_2 INIT...

Page 1769: ...r transfer i e READY output is active External transfer initiation The bus transfer action can be initiated externally by different inputs INIT_TR_1_2 Initiates any enabled transfer from feeder 1 to feeder 2 INIT_TR_2_1 Initiates any enabled transfer from feeder 2 to feeder 1 INIT_MANUAL Initiates manual transfer transfer direction depends on which direction is enabled in transfer direction block ...

Page 1770: ... can be enabled with setting Ena CB open transfer Transfer can be enabled to one direction only or to both directions Setting value 1 2 enables transfer from feeder 1 to feeder 2 Setting value 2 1 enables transfer from feeder 2 to feeder 1 Setting value both enables transfer to both directions Setting value Off disables the transfer initiation based on circuit breaker opening Activation based on C...

Page 1771: ...us transfer module diagram Function supports following transfer modes Fast transfer simultaneous control of both involved circuit breakers fastest mode sequential control of both involved circuit breakers Transfer at the 1st phase coincidence Residual voltage transfer Time delayed transfer Both fast transfer modes simultaneous and sequential are optimum transfer modes for ensuring only a minimum i...

Page 1772: ...fers All transfer mode s are reset if TR_RUNNING output changes from TRUE to FALSE If transfer is not successful and transfer is interrupted this is indicated with TR_CANCEL output The transfer modes are explained in next chapters Transfer sequence Bus transfer follows always certain sequence presented in Figure 940 Simultaneous fast transfer if enabled is attempted first If disabled or not succes...

Page 1773: ...alse then function executes simultaneous fast transfer In case Enable FBBM is set to true then function executes sequential transfer In simultaneous fast transfer circuit breaker open and close commands are issued at the same time see Figure 941 For uninterrupted transfer the HSABTC function carries out a fast transfer under the condition that busbar and stand by feeder are synchronous and other c...

Page 1774: ...A_RUN input is active transfer is not allowed to complete until input is deactivated When fast transfer is completed this is indicated with COMPL_FAST output Fast transfer sequential break before make FBBM Fast Sequential break before make transfer is activated if fast transfer has been enabled with Enable fast transfer defined in the previous chapter and Enable FBBM is True If fast sequential tra...

Page 1775: ...ed by Max angle Diff FBBM setting Phase angle evaluation includes circuit breaker closing time and frequency and frequency gradient of busbar voltage 1 2 4 Window for FBBM Window for fast transfer 3 5 Figure 942 Phase angle trajectory during fast sequential transfer FBBM 1 Synchronous conditions transfer initiation 2 Circuit breaker opening 3 Circuit breaker opening detected transfer conditions ar...

Page 1776: ...r opens stand by feeder close command CLOSE_CB2 4 Stand by feeder breaker closes If DISA_RUN input is active transfer is not allowed to complete until input is deactivated When fast sequential transfer is completed this is indicated with COMPL_FBBM output 1st phase transfer The transfer at the 1stst phase coincidence is executed when there are no synchronized conditions present at the moment of th...

Page 1777: ... timed is such way that at the closing time of the breaker phase angle difference between stand by feeder and busbar is close to zero The HSABTC determines the course of the difference voltage and the point in time of the 1st phase coincidence through anticipatory computation In order to compensate for the installation specific processing time system response time circuit breaker operating time th...

Page 1778: ... feeder voltage UBusbar Busbar voltage φ Angle between stand by voltage and busbar voltage dφ dt Angle speed between stand by voltage and busbar voltage Blue area Connection window dependent upon breaker closing time and dφ dt If DISA_RUN input is active transfer is not allowed to complete until input is deactivated When 1st phase transfer is completed this is indicated with COMPL_1ST_PH output Co...

Page 1779: ...is enabled with setting Ena Res V transfer The connection takes place without assessment of the angle or of the difference frequency thus in unsynchronized fashion Because the voltage of the busbars has however reached a sufficiently low residual voltage value the transient effects of the connection are manageable momentary jolt current needed for users to run up again voltage reduction Main feede...

Page 1780: ...ay setting If decoupling is activated this is indicated with CB_DECOUPL output Decoupling functionality can be enabled with setting Enable decoupling Enable decoupling has following modes Off decoupling functionality disabled CB man close decoupling is done when both connected breakers closed Note that this mode does not require active transfer for the decoupling Transfer based decoupling is done ...

Page 1781: ...TRUE if any of the following conditions are satisfied Instantaneous If the transfer is active TR_RUNNING is TRUE and Load shedding mode setting is Instantaneous the OPR_LOADSHED will be TRUE Load shedding is not activated during fast transfer Voltage based If the TR_RUNNING signal is TRUE and Load shedding mode setting is Voltage based and busbar voltage is less than Loadshed V limit Time based If...

Page 1782: ...ting Travel time Clc mode Supported calculation modes are shown in Table 1604 Table 1604 Supported traveling time measurement modes Setting values Description From Cmd to Pos Traveling time is measured from command to position change From Pos to Pos Traveling time is measured from position change to position change From Cmd to Curr Traveling time is measured from command till current is measured t...

Page 1783: ...uit breaker closing time measurement From Cmd to Pos From Cmd to Pos mode measures the closing time from binary output activation till position change has been indicated by auxiliary contacts Figure 949 shows an example of CB closing time measurement in From Cmd to Pos mode POSOPN_CB2 AUX BIN POSCLS_CB2 AUX BIN Current in Feeder 2 CB2 OPEN_CB2 FB CMD CLOSE_CB2 FB CMD RELAY BINARY OUTPUT Closing me...

Page 1784: ... Curr From Cmd to Curr measures the closing time from binary output activation till current is flowing in the primary circuit This operation mode requires that current signal is connected to I3P1 and I3P2 inputs POSOPN_CB2 AUX BIN POSCLS_CB2 AUX BIN Current in Feeder 2 CB2 OPEN_CB2 FB CMD CLOSE_CB2 FB CMD RELAY BINARY OUTPUT Closing me 1 2 3 Internal Logic BO ac va on delay Figure 950 Circuit brea...

Page 1785: ...available in total for each of the measurement The sets are saved in data banks 1 3 The data bank 1 of the respective measurement holds the most recent recorded data Older data are moved to the subsequent banks 1 2 and 2 3 When all three banks have data of a respective measurement and there is a new transfer complete operation the latest data set is placed into bank 1 and the data in bank 3 is ove...

Page 1786: ...Enum name Value Transfer mode None 0 Transfer mode Fast 1 Transfer mode FBBM 2 Transfer mode Phase coincidence 3 Transfer mode Res Voltage 4 Transfer mode Time delay 5 Transfer direction Unknown 0 Transfer direction Feeder 1 to Feeder 2 1 Transfer direction Feeder 2 to Feeder 1 2 Transfer cause None 0 Transfer cause External 1 Transfer cause External under voltage 2 Transfer cause Internal under f...

Page 1787: ...cause 0 5 Time delay transfer 6 None 0 None The transfer direction from feeder 1 to feeder 2 or vice versa is recorded by Transfer direction recorded data parameter The maximum rate of change of busbar voltage the maximum rate of change of frequency and frequency difference between stand by feeder and busbar busbar frequency busbar voltage phase angle difference between stand by feeder and busbar ...

Page 1788: ...One of the two feeder s circuit breaker is closed the other is open A parallel operation of both feeders is not intended If an error leads to an interruption of the feeder currently in operation say feeder 1 the transfer device switches the load over to the second feeder 2 in the shortest possible time Following successful transfer the busbar is then supplied by the second feeder 2 Once the main f...

Page 1789: ...n in the shortest possible time safely The primary functional mode of this function is the execution of fast transfer In this the commands are issued simultaneously to the respective circuit breakers which is to be opened or closed on condition that the feeders be synchronous with one another In the event of non synchronous feeders or break before make arrangements it offers a number 1MRS759142 F ...

Page 1790: ... by feeder The radius of inner circle represents the setting Min busbar voltage magnitude used for Fast and FBBM transfer The radius of innermost circle represents the setting Res voltage limit Fast transfer can occur if the busbar phasor lies in the zone Z1 defined by the area under curve ACDB after transfer initiation is active This area reflects the criterion for the fast transfer to occur i e ...

Page 1791: ...feeder and busbar voltages through anticipatory computation It estimates the phase angle difference between the stand by feeder and busbar voltage ahead of CB closing time keeping into account the prevailing frequency difference and rate of change of frequency difference between the stand by and busbar voltage It attempts to transfer such that phase angle difference is zero ideally zero practicall...

Page 1792: ...er configurations can be realized with the instances of this function M M Feeder 1 Feeder 2 CB1 CB2 BUSBAR M M Figure 954 Application package APP51 2 Circuit breaker configuration One busbar Transfer takes place between the two feeders Control functions 1MRS759142 F 1792 REX640 Technical Manual ...

Page 1793: ...configuration Two busbar sections Busbar coupling breaker Transfer between each feeder and bus coupling breaker Two instances of HSABTC function are required for this variant The first instance performs the transfer operation between feeder 1 and bus coupling breaker The second instance performs the transfer operation between feeder 2 and bus coupling breaker 1MRS759142 F Control functions REX640 ...

Page 1794: ...ration with pre selection One busbar 2 out of 3 selection Two instances of HSABTC function are required for this variant The first instance performs the transfer operation between feeder 1 and feeder 2 The second instance performs the transfer operation between feeder 1 and feeder 3 Control functions 1MRS759142 F 1794 REX640 Technical Manual ...

Page 1795: ...Application package APP53 M M Feeder 1 Feeder 2 CB1 CB2 BUSBAR M M Figure 957 Application package APP53 1MRS759142 F Control functions REX640 Technical Manual 1795 ...

Page 1796: ... this variant The first instance performs the transfer operation between feeder 1 and bus coupling breaker The second instance performs the transfer operation between feeder 2 and bus coupling breaker The third instance performs the transfer operation between feeder 1 and feeder 2 Application package APP53 M M Feeder 1 Feeder 2 CB1 CB2 BUSBAR M M Feeder 3 CB3 Figure 958 Application package APP53 C...

Page 1797: ... phase currents 2 U3P1 SIGNAL Three phase voltages Bus B side U3P2 SIGNAL Three phase voltages Bus A side U3P_BB SIGNAL Analog input BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode TRANSFER_ON BOOLEAN 0 False Level sensitive signal for enabling transfer ACT_LKOUT BOOLEAN 0 False Activate transfer lock out until function is reset INIT_MANUAL BOOLEAN 0 False Manual transfer ini ...

Page 1798: ...e Disable transfer com pletion when active ENA_FASTONLY BOOLEAN 0 False Enable fast transfer only POSOPN_CB1 BOOLEAN 0 False Signal for open po sition of apparatus from I O POSCLS_CB1 BOOLEAN 0 False Signal for close po sition of apparatus from I O POSOPN_CB2 BOOLEAN 0 False Signal for open po sition of apparatus from I O POSCLS_CB2 BOOLEAN 0 False Signal for close po sition of apparatus from I O ...

Page 1799: ... feeder 2 breaker CLOSE_CB2 BOOLEAN Close command for feeder 2 breaker OPR_LOADSHED BOOLEAN Activate load shedding CB_DECOUPL BOOLEAN CB decoupling activated COMPL_FAST BOOLEAN Fast transfer complete COMPL_FBBM BOOLEAN Fast break before make transfer complete COMPL_1ST_PH BOOLEAN First phase coincidence transfer complete COMPL_RES BOOLEAN Residual voltage based trans fer complete COMPL_TDLY BOOLEA...

Page 1800: ..._OK BOOLEAN Transfer is allowed from feeder 2 to feeder 1 LAST_TR_1_2 BOOLEAN Last valid transfer has been from feeder 1 to feeder 2 LAST_TR_2_1 BOOLEAN Last valid transfer has been from feeder 2 to feeder 1 AL_OPN_CB1 BOOLEAN Circuit breaker 1 opening time alarm AL_CLS_CB1 BOOLEAN Circuit breaker 1 closing time alarm AL_OPN_CB2 BOOLEAN Circuit breaker 2 opening time alarm AL_CLS_CB2 BOOLEAN Circu...

Page 1801: ...tings Advanced Parameter Values Range Unit Step Default Description Loadshed V limit 0 05 1 00 0 01 0 50 Busbar voltage lim it in load shedding Loadshed V time delay 0 200000 ms 10 0 Voltage based load shedding time de lay Loadshed time de lay 100 200000 ms 10 100 Load shedding time delay Table 1612 HSABTC Non group settings Basic Parameter Values Range Unit Step Default Description Operation 1 on...

Page 1802: ...0 Time delayed trans fer activation time Max Trn run time 100 200000 ms 1 5000 Maximum transfer running time Travel time Clc mode 1 From Cmd to Pos 2 From Pos to Pos 3 From Cmd to Curr 4 From Pos to Curr 1 From Cmd to Pos Travel time calcu lation mode selec tion CB open alarm time 0 1000 ms 1 60 Alarm level setting for open travel time in ms CB close alarm time 0 1000 ms 1 80 Alarm level setting f...

Page 1803: ...eady no sync 5 Transfer running 6 Not defined Transfer status FRQ_DIFF FLOAT32 30 00 30 00 Hz Frequency difference between standby feed er and busbar ANG_DIFF_1 FLOAT32 180 0 180 0 deg Angle difference be tween feeder 1 and bus bar ANG_DIFF_2 FLOAT32 180 0 180 0 deg Angle difference be tween feeder 2 and bus bar CLS_T_CB1 FLOAT32 0 0 10000 0 ms Measured close time for circuit breaker of feeder 1 C...

Page 1804: ...n transfer initiation and CB close command Busbar Max dv dt FLOAT32 100 00 100 00 Maximum rate of change of busbar volt age Busbar Max df dt FLOAT32 100 00 100 00 Maximum rate of change of frequency of busbar voltage Busbar voltage FLOAT32 0 0 10 0 Busbar voltage at the time of CB close com mand Busbar frequency FLOAT32 35 00 75 00 Hz Busbar frequency at the time of CB close com mand Phase differe...

Page 1805: ...CB close com mand Busbar frequency FLOAT32 35 00 75 00 Hz Busbar frequency at the time of CB close com mand Phase difference FLOAT32 180 0 180 0 deg Busbar and standby feeder phase diff at CB close command CB decoupled BOOLEAN 0 False 1 True CB decoupling hap pened during the trans fer Loadshed operated BOOLEAN 0 False 1 True Load shedding operat ed during transfer Triggering time Timestamp Trigge...

Page 1806: ...a Characteristic Value Operation accuracy Voltage 1 5 of the set value or 0 002 Un frequency range 10Hz Frequency 25mHz of the set value Initiation time Minimum Typical Maximum Under voltage1 2 3 14 ms 18 ms 21 ms Under frequency2 3 4 47 ms 49 ms 50 ms External binary in put 2 3 5 9 ms 10 ms 12 ms Initiation time accuracy 20 ms of the set value Operate time accuracy 1 0 of the set value or 20 ms 1...

Page 1807: ... 1 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Current total demand harmonic distortion DC component TDD THD DC and individual harmonics CHMHAI PQM3IH PQM ITHD IDC 10 1 2 Function block Figure 959 Function block 1MRS759142 F Power quality measurement functions REX640 Technical Manual 1807 ...

Page 1808: ... quality standards include EN 50160 2010 IEEE 519 2014 IEC 61000 4 7 2002 A1 2008 and IEC 61000 4 30 2015 10 1 4 Analog channel configuration CHMHAI has one analog group input which must be properly configured Table 1616 Analog inputs Input Description I3P Three phase currents See the preprocessing function blocks in this document for the possible signal sources Improper analog channel configurati...

Page 1809: ...the 11th harmonic The filter used for harmonics includes a spectrum of frequencies near each harmonic frequency FFT for one period is used The resulting frequency spectrum is wider than in a harmonic subgroup An anti aliasing filter is used 10 1 5 2 Total harmonic distortion The total harmonic distortion THD is calculated from the measured harmonic components with the formula THD I I h h n 1 2 2 E...

Page 1810: ...cks See also Figure 961 and the description for sliding values 10 1 5 4 Harmonic calculation Harmonic mean values are calculated for each phase Also the mean values of the nominal frequency fundamental and direct current component are calculated The fundamental frequency mean values are shown as percentage of the nominal phase current The actual harmonic mean values are shown as percentage of the ...

Page 1811: ...current component outputs are SMNDC_A SMNDC_B and SMNDC_C Intervals that are longer than 3 seconds are calculated using free running 3 second mean values The longer 10 minute mean values of the fundamental of each phase are seen in monitored data as LMNH01_A LMNH01_B and LMNH01_C Actual harmonics are seen with their number Direct current components are LMNDC_A LMNDC_B and LMNDC_C Time stamps for r...

Page 1812: ...rrent similar to varying fundamental current Changing setting Sliding interval has influence on the seen mean values Sliding values change slowly towards the input value during the time interval When mean values have not been calculated for a full interval quality is marked questionable in the IEC 61850 data Questionable quality is also indicated for a full interval if the protection relay is rese...

Page 1813: ... THD or TDD mean values are collected from all three phases Individual harmonics and the fundamental frequency component can also be collected 1MRS759142 F Power quality measurement functions REX640 Technical Manual 1813 ...

Page 1814: ... value of DC compo nent for Phase B SMNDC_C FLOAT32 Shorter mean value of DC compo nent for Phase C SMNH01_A FLOAT32 Shorter mean value of basic freq for Phase A SMNH01_B FLOAT32 Shorter mean value of basic freq for Phase B SMNH01_C FLOAT32 Shorter mean value of basic freq for Phase C SMNH02_A FLOAT32 Shorter mean value of 2nd harmon ic for Phase A SMNH02_B FLOAT32 Shorter mean value of 2nd harmon...

Page 1815: ... value of 7th harmonic for Phase C SMNH08_A FLOAT32 Shorter mean value of 8th harmonic for Phase A SMNH08_B FLOAT32 Shorter mean value of 8th harmonic for Phase B SMNH08_C FLOAT32 Shorter mean value of 8th harmonic for Phase C SMNH09_A FLOAT32 Shorter mean value of 9th harmonic for Phase A SMNH09_B FLOAT32 Shorter mean value of 9th harmonic for Phase B SMNH09_C FLOAT32 Shorter mean value of 9th ha...

Page 1816: ...current for harmonic de mand calculation 10 1 9 Monitored data Table 1621 CHMHAI Monitored data Name Type Values Range Unit Description LMNTHD_A FLOAT32 0 00 500 00 Mean THD for phase A in 10 min non sliding mean in LMNTHD_B FLOAT32 0 00 500 00 Mean THD for phase B in 10 min non sliding mean in LMNTHD_C FLOAT32 0 00 500 00 Mean THD for phase C in 10 min non sliding mean in LMNTDD_A FLOAT32 0 00 50...

Page 1817: ...0 500 00 Longer mean val ue of 2nd har monic for Phase A in LMNH02_B FLOAT32 0 00 500 00 Longer mean val ue of 2nd har monic for Phase B in LMNH02_C FLOAT32 0 00 500 00 Longer mean val ue of 2nd har monic for Phase C in LMNH03_A FLOAT32 0 00 500 00 Longer mean val ue of 3rd har monic for Phase A in LMNH03_B FLOAT32 0 00 500 00 Longer mean val ue of 3rd har monic for Phase B in LMNH03_C FLOAT32 0 0...

Page 1818: ... har monic for Phase B in LMNH06_C FLOAT32 0 00 500 00 Longer mean val ue of 6th har monic for Phase C in LMNH07_A FLOAT32 0 00 500 00 Longer mean val ue of 7th har monic for Phase A in LMNH07_B FLOAT32 0 00 500 00 Longer mean val ue of 7th har monic for Phase B in LMNH07_C FLOAT32 0 00 500 00 Longer mean val ue of 7th har monic for Phase C in LMNH08_A FLOAT32 0 00 500 00 Longer mean val ue of 8th...

Page 1819: ...NH10_C FLOAT32 0 00 500 00 Longer mean val ue of 10th har monic for Phase C in LMNH11_A FLOAT32 0 00 500 00 Longer mean val ue of 11th har monic for Phase A in LMNH11_B FLOAT32 0 00 500 00 Longer mean val ue of 11th har monic for Phase B in LMNH11_C FLOAT32 0 00 500 00 Longer mean val ue of 11th har monic for Phase C in L time stamp Timestamp Time stamp of end of 10 min mean values 10 1 10 Technic...

Page 1820: ... harmonic distortion DC component THD DC and indi vidual harmonics VHMHAI PQM3VH PQM VTHD VDC 10 2 2 Function block Figure 963 Function block 10 2 3 Functionality Harmonic voltage values are available as measurements for each harmonic and THD There are also direct current component and fundamental frequency values The values of three phases are calculated separately Power quality measurement funct...

Page 1821: ...hree phase voltages for voltage harmonic measurement function VHMHAI See the preprocessing function blocks in this document for the possible signal sources There are a few special conditions which must be noted with the configuration Table 1624 Special conditions Condition Description U3P connected to real meas urements The function requires that all three voltage channels are con nected Improper ...

Page 1822: ...iasing filter is used 10 2 5 2 Total harmonic distortion The total harmonic distortion THD is calculated from the measured harmonic components with the formula THD I I h h n 1 2 2 Equation 392 Ih hth harmonic component I1 Fundamental voltage 1st harmonic n Number of harmonics THD shorter mean value outputs are SMNTHD_A SMNTHD_B and SMNTHD_C These and also the 10 minute mean values LMNTHD_A LMNTHD_...

Page 1823: ...e every 0 1 seconds Figure 965 Sliding 3 seconds value calculation in principle The shorter mean values of the fundamental of each phase are SMNH01_A SMNH01_B and SMNH01_C Actual harmonics are seen with their number for example phase A for second harmonic is SMNH02_A and phase C for 9th harmonic is SMNH09_C Direct current component outputs are SMNDC_A SMNDC_B and SMNDC_C Intervals that are longer ...

Page 1824: ...ality is marked as bad in the IEC 61850 data Bad quality is also indicated after the protection relay has been reset 10 2 6 Application Typically the measured short time 3 second mean values are used with a suitable logic to give alarms If a more stabilized value is needed a 1 minute or 5 minute mean value should be selected One example of using short time mean values is to compare the level of TH...

Page 1825: ...alue of basic freq for Phase B SMNH01_C FLOAT32 Shorter mean value of basic freq for Phase C SMNH02_A FLOAT32 Shorter mean value of 2nd harmon ic for Phase A SMNH02_B FLOAT32 Shorter mean value of 2nd harmon ic for Phase B SMNH02_C FLOAT32 Shorter mean value of 2nd harmon ic for Phase C SMNH03_A FLOAT32 Shorter mean value of 3rd harmonic for Phase A SMNH03_B FLOAT32 Shorter mean value of 3rd harmo...

Page 1826: ... A SMNH08_B FLOAT32 Shorter mean value of 8th harmonic for Phase B SMNH08_C FLOAT32 Shorter mean value of 8th harmonic for Phase C SMNH09_A FLOAT32 Shorter mean value of 9th harmonic for Phase A SMNH09_B FLOAT32 Shorter mean value of 9th harmonic for Phase B SMNH09_C FLOAT32 Shorter mean value of 9th harmonic for Phase C SMNH10_A FLOAT32 Shorter mean value of 10th harmon ic for Phase A SMNH10_B FL...

Page 1827: ...B FLOAT32 0 00 500 00 Longer mean value of DC component for Phase B in LMNDC_C FLOAT32 0 00 500 00 Longer mean value of DC component for Phase C in LMNH01_A FLOAT32 0 00 500 00 Longer mean value of basic freq for Phase A in LMNH01_B FLOAT32 0 00 500 00 Longer mean value of basic freq for Phase B in LMNH01_C FLOAT32 0 00 500 00 Longer mean value of basic freq for Phase C in LMNH02_A FLOAT32 0 00 50...

Page 1828: ...32 0 00 500 00 Longer mean value of 7th harmonic for Phase A in LMNH07_B FLOAT32 0 00 500 00 Longer mean value of 7th harmonic for Phase B in LMNH07_C FLOAT32 0 00 500 00 Longer mean value of 7th harmonic for Phase C in LMNH08_A FLOAT32 0 00 500 00 Longer mean value of 8th harmonic for Phase A in LMNH08_B FLOAT32 0 00 500 00 Longer mean value of 8th harmonic for Phase B in LMNH08_C FLOAT32 0 00 50...

Page 1829: ...stic Value Operation accuracy Nominal frequency 50 Hz Harmonics in the range 0 0 21 fundamental amplitude 3 0 or 0 2 10 3 Voltage variation PHQVVR ANSI PQMV SWE SAG INT 10 3 1 Identification Function description IEC 61850 identification IEC 60617 identification ANSI IEEE C37 2 device number Voltage variation PHQVVR PQMU PQMV SWE SAG INT 10 3 2 Function block Figure 967 Function block 10 3 3 Functi...

Page 1830: ...voltages See the preprocessing function blocks in this document for the possible signal sources The GRPOFF signal is available in the function block called Protection There are a few special conditions which must be noted with the configuration Table 1631 Special conditions Condition Description U3P connected to real meas urements The function can work with one voltage channel connected A B or C d...

Page 1831: ...ard There is no dependence between the phases for variation start The START output and the corresponding phase start are activated when the limit is exceeded or undershot The corresponding phase start deactivation takes place when the limit includes small hysteresis is undershot or exceeded The START output is deactivated when there are no more active phases However when Phase mode is Three Phase ...

Page 1832: ...ted when the measured TRMS value drops below the Voltage dip set 3 setting in one phase and also remains above the Voltage Int set setting If the voltage drops below the Voltage Int set setting the output INTST is activated INTST is deactivated when the voltage value rises above the setting Voltage Int set When the same measured TRMS magnitude rises above the setting Voltage swell set 3 the SWELLS...

Page 1833: ...epth are defined as percentage values calculated from the difference between the reference and the measured voltage For example a dip to 70 percent means that the minimum voltage dip magnitude variation is 70 percent of the reference voltage amplitude The activation of the BLOCK input resets the function and outputs 10 3 5 3 Variation validation The validation criterion for voltage variation is th...

Page 1834: ... the activation of the OPERATE output and recording data update takes place These counters are available through the monitored data view on the LHMI or through tools via communications There are no phase segregated counters but all the variation detections are registered to a common time magnitude classified counter type Consequently a simultaneous multiphase event that is the variation type event...

Page 1835: ...efore rising back above Voltage dip set 3 The event indication ends and possible detection is done when the TRMS voltage returns above for dip and interruption or below for swell the activation starting limit For example after an instantaneous dip the event indication when the voltage magnitude exceeds Voltage dip set 1 is not detected and recorded immediately but only if no longer dip indication ...

Page 1836: ...lity built in function that checks the relationship adherence so that if VVa x time 1 is set higher than VVa x time 2 or VVa x time 3 VVa x time 2 and VVa x time 3 are set equal to the new VVa x time 1 If VVa x time 2 is set higher than VVa x time 3 VVa x time 3 is set to the new VVa x time 2 If VVa x time 2 is set lower than VVa x time 1 the entered VVa x time 2 is rejected If VVa x time 3 is set...

Page 1837: ... fulfilled variation is indicated as a dip as long as all phases are active In case of a single phase interruption of Chapter 10 3 5 4 Duration measurement when there is a dip indicated in another phase but the third phase is not active there is no variation indication start when Phase mode is Three Phase In this case only the Phase Mode value Single Phase results in the ST_B interruption and the ...

Page 1838: ...all the phases are active Furthermore both swell and dip variation event detections take place simultaneously In case of a concurrent voltage dip and voltage swell both SWELLCNT and DIPCNT are incremented by one Also Figure 975 shows that for the Phase mode value Three Phase two different time moment variation event swell detections take place and consequently DIPCNT is incremented by one but SWEL...

Page 1839: ...swell 10 3 6 Recorded data Besides counter increments the information required for a later fault analysis is stored after a valid voltage variation is detected Recorded data information When voltage variation starts the phase current magnitudes preceding the activation moment are stored Also the initial voltage magnitudes are temporarily stored at the variation starting moment If the variation is ...

Page 1840: ...e older data sets are moved to the next banks 1 2 and 2 3 when a valid voltage variation is detected When all three banks have data and a new variation is detected the newest data are placed into bank 1 and the data in bank 3 are overwritten by the data from bank 2 Figure 976 shows a valid recorded voltage interruption and two dips for the Phase mode value Single Phase The first dip event duration...

Page 1841: ...ariation duration Ph B Variation Dur Ph B Variation Ph B start time stamp phase B var iation start time moment Var Dur Ph B time Variation duration Ph C Variation Dur Ph C Variation Ph C start time stamp phase C var iation start time moment Var Dur Ph C time Current magnitude Ph A preceding variation Var current Ph A Current magnitude Ph B preceding variation Var current Ph B Current magnitude Ph ...

Page 1842: ... equipment Voltage dips are typically caused by faults occurring in the power distribution system Typical reasons for the faults are lightning strikes and tree contacts In addition to fault situations the switching of heavy loads and starting of large motors also cause dips Voltage swells cause extra stress for the network components and the devices connected to the power system Voltage swells are...

Page 1843: ...VVR Input signals Name Type Default Description I3P SIGNAL Three phase currents U3P SIGNAL Three phase voltages BLOCK BOOLEAN 0 False Block signal for acti vating the blocking mode 10 3 8 2 PHQVVR Output signals Table 1635 PHQVVR Output signals Name Type Description OPERATE BOOLEAN Voltage variation detected START BOOLEAN Voltage variation present SWELLST BOOLEAN Voltage swell active DIPST BOOLEAN...

Page 1844: ...ion 3 Voltage Int set 0 0 100 0 0 1 10 0 Interruption limit in of reference volt age VVa Int time 1 0 5 30 0 cycles 0 1 3 0 Voltage variation Int duration 1 VVa Int time 2 10 0 180 0 cycles 0 1 30 0 Voltage variation Int duration 2 VVa Int time 3 2000 60000 ms 10 3000 Voltage variation interruption dura tion 3 VVa Dur Max 100 3600000 ms 100 60000 Maximum voltage variation duration Table 1637 PHQVV...

Page 1845: ...nter INSTDIPCNT INT32 0 2147483647 Instantaneous dip oper ation counter MOMDIPCNT INT32 0 2147483647 Momentary dip opera tion counter TEMPDIPCNT INT32 0 2147483647 Temporary dip opera tion counter MAXDURDIPCNT INT32 0 2147483647 Maximum duration dip operation counter MOMINTCNT INT32 0 2147483647 Momentary interrup tion operation counter TEMPINTCNT INT32 0 2147483647 Temporary interruption operatio...

Page 1846: ...ent magnitude Phase A preceding var iation Var current Ph B FLOAT32 0 00 60 00 xIn Current magnitude Phase B preceding var iation Var current Ph C FLOAT32 0 00 60 00 xIn Current magnitude Phase C preceding var iation Time Timestamp Time Variation type Enum 0 No variation 1 Swell 2 Dip 3 Swell dip 4 Interruption 5 Swell Int 6 Dip Int 7 Swell dip Int Variation type Variation Ph A FLOAT32 0 00 5 00 x...

Page 1847: ...h B FLOAT32 0 00 5 00 xUref Variation magnitude Phase B Var Ph B rec time Timestamp Variation magnitude Phase B time stamp Variation Ph C FLOAT32 0 00 5 00 xUref Variation magnitude Phase C Var Ph C rec time Timestamp Variation magnitude Phase C time stamp Variation Dur Ph A FLOAT32 0 000 3600 000 s Variation duration Phase A Var Dur Ph A time Timestamp Variation Ph A start time stamp Variation Du...

Page 1848: ...ity of providing a high quality that is a balanced voltage supply on a continuous basis VSQVUB uses five different methods for calculating voltage unbalance The methods are the negative sequence voltage magnitude zero sequence voltage magnitude ratio of the negative sequence voltage magnitude to the positive sequence voltage magnitude ratio of the zero sequence voltage magnitude to the positive se...

Page 1849: ...ltage channels Further if VT connection is Delta in that particular UTVTR the Unb detection method cannot be set to Zero Seq or Zero to Pos Seq Improper analog channel configuration causes a validation error if the analog channels are not completely configured or they do not match with certain settings For troubleshooting check the contents of this chapter and also the preprocessing blocks in this...

Page 1850: ...alculated based on the ratio of the negative sequence voltage magnitude to the positive sequence magnitude When the Zero to Pos Seq mode is selected the voltage unbalance is calculated based on the ratio of the zero sequence voltage magnitude to the positive sequence magnitude When the Ph vectors Comp mode is selected the ratio of the maximum phase voltage magnitude deviation from the mean voltage...

Page 1851: ...and Obs period Str hour are used to set the calendar time in UTC These settings have to be adjusted according to the local time and local daylight saving time A preferable way of continuous statistics recordings can be selected over a longer period months years With the Trigger mode setting the way the next possible observation time is activated after the former one has finished can be selected Ta...

Page 1852: ...isables the maximum value calculation of the Statistics recorder module If the trigger mode is selected Periodic or Continuous and the blocking is deactivated before the next observation period is due to start the scheduled period starts normally 10 4 5 5 Statistics recorder The Statistics recorder module provides readily calculated three second or ten minute values of the selected phase to the pe...

Page 1853: ... whole period before the next period completes The BLOCK input blocks the output PCT_UNB_VAL 10 4 5 7 Recorded data The information required for a later fault analysis is stored when the Recorded data module is triggered This happens when a voltage unbalance is detected by the Voltage unbalance detector module Three sets of recorded data are available in total The sets are saved in data banks 1 3 ...

Page 1854: ...y the network and load unbalance that may cause sustained voltage unbalance A single phase or phase to phase fault in the network or load side can create voltage unbalance but as faults are usually isolated in a short period of time the voltage unbalance is not a sustained one Therefore the voltage unbalance may not be covered by VSQVUB Another major application is the long term power quality moni...

Page 1855: ... Range Unit Step Default Description Operation 1 on 5 off 1 on Operation On Off Unb detection method 1 Neg Seq 2 Zero Seq 3 Neg to Pos Seq 4 Zero to Pos Seq 5 Ph vectors Comp 3 Neg to Pos Seq Set the operation mode for voltage unbalance calcula tion Unbalance start Val 1 100 1 1 Voltage unbalance start value Trigger mode 1 Single 2 Periodic 3 Continuous 3 Continuous Specifies the ob servation peri...

Page 1856: ...0 Non sliding 3 second mean value of voltage unbalance 10MIN_MN_UNB FLOAT32 0 00 150 00 Sliding 10 minutes mean value of voltage unbalance PCT_UNB_VAL FLOAT32 0 00 150 00 Limit below which per centile unbalance of the values lie MAX_UNB_VAL FLOAT32 0 00 150 00 Maximum voltage un balance measured in the observation period MAX_UNB_TIME Timestamp Time stamp at which maximum voltage un balance measure...

Page 1857: ... 0 000 3600 000 s Time duration for alarm high mean unbalance Max unbalance Volt FLOAT32 0 00 150 00 Maximum 3 seconds unbalance voltage Time Max Unb Volt Timestamp Time stamp of maxi mum voltage unbalance VSQVUB Enum 1 on 2 blocked 3 test 4 test blocked 5 off Status 10 4 10 Technical data Table 1649 VSQVUB Technical data Characteristic Value Operation accuracy 1 5 of the set value or 0 002 Un Res...

Page 1858: ... determined solely with the Reset delay time setting The purpose of the delayed reset is to enable fast clearance of intermittent faults for example self sealing insulation faults and severe faults which may produce high asymmetrical fault currents that partially saturate the current transformers It is typical for an intermittent fault that the fault current contains so called drop off periods dur...

Page 1859: ...p off In case 1 the reset is delayed with the Reset delay time setting and in case 2 the counter is reset immediately because the Reset delay time setting is set to zero 1MRS759142 F General function block features REX640 Technical Manual 1859 ...

Page 1860: ...he current is below the set Start value and the set hysteresis region The timer input rises when a fault current is detected The definite timer activates the START output and the operate timer starts elapsing The reset drop off timer starts when the timer input falls that is the fault disappears When the reset drop off timer elapses the operate timer is reset Since this happens before another star...

Page 1861: ...t is below the set Start value and the set hysteresis region The timer input rises when a fault current is detected The definite timer activates the START output and the operate timer starts elapsing The Reset drop off timer starts when the timer input falls that is the fault disappears Another fault situation occurs before the reset drop off timer has elapsed This causes the activation of the OPE...

Page 1862: ...n during the time BLOCK remains active If the timer input is not active longer than specified by the Reset delay time setting the operate timer is reset in the same way as described in Figure 983 regardless of the BLOCK input The selected blocking mode is Freeze timer 11 2 Current based inverse definite minimum time characteristics General function block features 1MRS759142 F 1862 REX640 Technical...

Page 1863: ...out the inverse time characteristic The Minimum operate time setting defines the minimum operating time for the IDMT curve that is the operation time is always at least the Minimum operate time setting Alternatively the IDMT Sat point is used for giving the leveling out point as a multiple of the Start value setting Global setting Configuration System IDMT Sat point The default parameter value is ...

Page 1864: ...e based on the IDMT characteristic leveled out with the Minimum operate time setting is set to 1000 milliseconds the IDMT Sat point setting is set to maximum General function block features 1MRS759142 F 1864 REX640 Technical Manual ...

Page 1865: ...on time curve based on the IDMT characteristic leveled out with IDMT Sat point setting value 11 the Minimum operate time setting is set to minimum 1MRS759142 F General function block features REX640 Technical Manual 1865 ...

Page 1866: ...ent is outside the guaranteed measuring range Also the maximum measured current of 50 x In gives the leveling out point 50 2 5 20 x I I 11 2 1 1 Standard inverse time characteristics For inverse time operation both IEC and ANSI IEEE standardized inverse time characteristics are supported The operate times for the ANSI and IEC IDMT curves are defined with the coefficients A B and C The values of th...

Page 1867: ...In verse 0 0086 0 0185 0 02 4 ANSI Moderately Inverse 0 0515 0 1140 0 02 6 Long Time Ex tremely Inverse 64 07 0 250 2 0 7 Long Time Very In verse 28 55 0 712 2 0 8 Long Time Inverse 0 086 0 185 0 02 9 IEC Normal Inverse 0 14 0 0 0 02 10 IEC Very Inverse 13 5 0 0 1 0 11 IEC Inverse 0 14 0 0 0 02 12 IEC Extremely In verse 80 0 0 0 2 0 13 IEC Short Time Inverse 0 05 0 0 0 04 14 IEC Long Time In verse...

Page 1868: ...Figure 989 ANSI extremely inverse time characteristics General function block features 1MRS759142 F 1868 REX640 Technical Manual ...

Page 1869: ...Figure 990 ANSI very inverse time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1869 ...

Page 1870: ...Figure 991 ANSI normal inverse time characteristics General function block features 1MRS759142 F 1870 REX640 Technical Manual ...

Page 1871: ...Figure 992 ANSI moderately inverse time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1871 ...

Page 1872: ...Figure 993 ANSI long time extremely inverse time characteristics General function block features 1MRS759142 F 1872 REX640 Technical Manual ...

Page 1873: ...Figure 994 ANSI long time very inverse time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1873 ...

Page 1874: ...Figure 995 ANSI long time inverse time characteristics General function block features 1MRS759142 F 1874 REX640 Technical Manual ...

Page 1875: ...Figure 996 IEC normal inverse time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1875 ...

Page 1876: ...Figure 997 IEC very inverse time characteristics General function block features 1MRS759142 F 1876 REX640 Technical Manual ...

Page 1877: ...Figure 998 IEC inverse time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1877 ...

Page 1878: ...Figure 999 IEC extremely inverse time characteristics General function block features 1MRS759142 F 1878 REX640 Technical Manual ...

Page 1879: ...Figure 1000 IEC short time inverse time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1879 ...

Page 1880: ...time characteristics 11 2 1 2 User programmable inverse time characteristics The user can define curves by entering parameters into the following standard formula General function block features 1MRS759142 F 1880 REX640 Technical Manual ...

Page 1881: ... characteristics The RI type simulates the behavior of electromechanical relays The RD type is an earth fault specific characteristic The RI type is calculated using the formula t s k I I 0 339 0 236 Equation 395 The RD type is calculated using the formula t s I k I 5 8 1 35 In Equation 396 t s Operate time in seconds k Set Time multiplier I Measured current I Set Start value 1MRS759142 F General ...

Page 1882: ...Figure 1002 RI type inverse time characteristics General function block features 1MRS759142 F 1882 REX640 Technical Manual ...

Page 1883: ...ime characteristic The UK rectifier type simulates the rectifier bridge The operate times are defined with the coefficients A B and C The values of the coefficients can be calculated according to the formula 1MRS759142 F General function block features REX640 Technical Manual 1883 ...

Page 1884: ... Measured current I Set Start value k Set Time multiplier Table 1651 Curve parameters for UK rectifier Operating curve type A B C 20 UK rectifier 45900 0 5 6 General function block features 1MRS759142 F 1884 REX640 Technical Manual ...

Page 1885: ...Figure 1004 UK rectifier inverse time characteristic 1MRS759142 F General function block features REX640 Technical Manual 1885 ...

Page 1886: ...alue including hysteresis The integral sum of the inverse time counter is reset if another start does not occur during the reset delay If the Type of reset curve setting is selected as Def time reset the current level has no influence on the reset characteristic Inverse reset Inverse reset curves are available only for ANSI and user programmable curves If you use other curve types immediate reset ...

Page 1887: ...0 46 4 ANSI Moderately Inverse 4 85 6 Long Time Extremely Inverse 30 7 Long Time Very Inverse 13 46 8 Long Time Inverse 4 6 The delayed inverse reset time depends also on the protection function s start duration value START_DUR The reset time on the drop off moment can be calculated by multiplying t s with START_DUR 1MRS759142 F General function block features REX640 Technical Manual 1887 ...

Page 1888: ...Figure 1005 ANSI extremely inverse reset time characteristics General function block features 1MRS759142 F 1888 REX640 Technical Manual ...

Page 1889: ...Figure 1006 ANSI very inverse reset time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1889 ...

Page 1890: ...Figure 1007 ANSI normal inverse reset time characteristics General function block features 1MRS759142 F 1890 REX640 Technical Manual ...

Page 1891: ...Figure 1008 ANSI moderately inverse reset time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1891 ...

Page 1892: ...Figure 1009 ANSI long time extremely inverse reset time characteristics General function block features 1MRS759142 F 1892 REX640 Technical Manual ...

Page 1893: ...Figure 1010 ANSI long time very inverse reset time characteristics 1MRS759142 F General function block features REX640 Technical Manual 1893 ...

Page 1894: ...et is not available for IEC type inverse time curves User programmable delayed inverse reset The user can define the delayed inverse reset time characteristics with the following formula using the set Curve parameter D General function block features 1MRS759142 F 1894 REX640 Technical Manual ...

Page 1895: ... This may be the case for example when the inverse time function of a protection relay needs to be blocked to enable the definite time operation of another protection relay for selectivity reasons especially if different relaying techniques old and modern relays are applied The selected blocking mode is Freeze timer The activation of the BLOCK input also lengthens the minimum delay value of the ti...

Page 1896: ...sum of the integrator calculating the overvoltage situation exceeds the value set by the inverse time mode The set value depends on the selected curve type and the setting values used The user determines the curve scaling with the Time multiplier setting The Minimum operate time setting defines the minimum operate time for the IDMT mode that is it is possible to limit the IDMT based operate time f...

Page 1897: ...se time characteristics for overvoltage protection The operate times for the standard overvoltage IDMT curves are defined with the coefficients A B C D and E The inverse operate time can be calculated with the formula t s k A B U U U C D E Equation 399 1MRS759142 F General function block features REX640 Technical Manual 1897 ...

Page 1898: ...f Time multiplier Table 1654 Curve coefficients for the standard overvoltage IDMT curves Curve name A B C D E 17 Inverse Curve A 1 1 0 0 1 18 Inverse Curve B 480 32 0 5 0 035 2 19 Inverse Curve C 480 32 0 5 0 035 3 General function block features 1MRS759142 F 1898 REX640 Technical Manual ...

Page 1899: ...Figure 1014 Inverse curve A characteristic of overvoltage protection 1MRS759142 F General function block features REX640 Technical Manual 1899 ...

Page 1900: ...Figure 1015 Inverse curve B characteristic of overvoltage protection General function block features 1MRS759142 F 1900 REX640 Technical Manual ...

Page 1901: ...age protection 11 3 1 2 User programmable inverse time characteristics for overvoltage protection The user can define the curves by entering the parameters using the standard formula 1MRS759142 F General function block features REX640 Technical Manual 1901 ...

Page 1902: ...t The Curve Sat Relative setting for curves A B and C is 2 0 percent However it should be noted that the user must carefully calculate the curve characteristics concerning the discontinuities in the curve when the programmable curve equation is used Thus the Curve Sat Relative parameter gives another degree of freedom to move the inverse curve on the voltage ratio axis and it effectively sets the ...

Page 1903: ... IDMT curves are defined with the coefficients A B C D and E The inverse operate time can be calculated with the formula t s k A B U U U C D E Equation 401 t s Operate time in seconds U Measured voltage U Set value of the Start value setting k Set value of the Time multiplier setting Table 1655 Curve coefficients for standard undervoltage IDMT curves Curve name A B C D E 21 Inverse Curve A 1 1 0 0...

Page 1904: ...Figure 1017 Inverse curve A characteristic of undervoltage protection General function block features 1MRS759142 F 1904 REX640 Technical Manual ...

Page 1905: ...voltage protection 11 3 2 2 User programmable inverse time characteristics for undervoltage protection The user can define curves by entering parameters into the standard formula 1MRS759142 F General function block features REX640 Technical Manual 1905 ...

Page 1906: ...r it should be noted that the user must carefully calculate the curve characteristics concerning also discontinuities in the curve when the programmable curve equation is used Thus the Curve Sat Relative parameter gives another degree of freedom to move the inverse curve on the voltage ratio axis and it effectively sets the maximum operate time for the IDMT curve because for the voltage ratio valu...

Page 1907: ...cy adaptivity to Main frequency source One additional UTVTR or ILTCTR can be set to Backup frequency source For main or backup frequency source all three phases must be connected Each TxTR block that is set to Frequency adaptivity mode enable outputs measurements adapted to either main or backup source frequency depending on their availability See the Preprocessing blocks chapter for more informat...

Page 1908: ... the network by closing the circuit breaker the designated start up overcurrent function should be either blocked or its start value increased as the Start value setting is typically lower than the nominal current 11 6 Measurement modes In many current or voltage dependent function blocks there are various alternative measuring principles RMS DFT which is a numerically calculated fundamental compo...

Page 1909: ...ode is usually used in conjunction with high and instantaneous stages where the suppression of harmonics is not so important In addition the peak to peak mode allows considerable CT saturation without impairing the performance of the operation Peak to peak with peak backup The peak to peak with peak backup measurement principle is selected with the Measurement mode setting using the value P to P b...

Page 1910: ...rent frequency is 10 85 Hz 11 7 Calculated measurements Calculated residual current and voltage The residual current is calculated from the phase currents according to equation Io I I I A B C Equation 404 The residual voltage is calculated from the phase to earth voltages when the VT connection is selected as Wye with the equation Uo U U U A B C 3 Equation 405 Sequence components The phase sequenc...

Page 1911: ...ated from the phase to phase voltages when VT connection is selected as Delta according to the equations U U U U A AB CA 0 3 Equation 414 U U U U B BC AB 0 3 Equation 415 U U U U C CA BC 0 3 Equation 416 If the U0 channel is not valid it is assumed to be zero The phase to phase voltages are calculated from the phase to earth voltages when VT connection is selected as Wye according to the equations...

Page 1912: ...but ACT configuration can be used to block physical outputs to process Control function com mands blocked TRUE FALSE IED test Protection works as in Normal mode but protection functions work in parallel with test parame ters FALSE TRUE IED test and blocked Protection works as in Normal mode but protection functions work in parallel with the test pa rameter The ACT configuration can be used to bloc...

Page 1913: ...ormal operation FALSE Blocked Control function commands blocked TRUE Off Control functions disabled FALSE See function block Control for more details The behavior data objects under CTRL logical device follow CTRL LLN0 Mod value If On is selected behavior data objects follow the mode of the corresponding logical device 11 8 4 Application configuration and Control mode The physical outputs from com...

Page 1914: ...al Yes No access No access No access Local Remote Mainte nance Yes Command originator cat egory maintenance No access No access Local Remote All levels Yes All originator categories Yes No access Binary input No access No access No access Yes 11 8 6 LHMI indications The Home button flashes green with low frequency indicating that one of the test mode options that is IED blocked IED test and blocke...

Page 1915: ...ted accuracy limit primary current to the rated primary current For example a protective current transformer of type 5P10 has the accuracy class 5P and the accuracy limit factor 10 For protective current transformers the accuracy class is designed by the highest permissible percentage composite error at the rated accuracy limit primary current prescribed for the accuracy class concerned followed b...

Page 1916: ...suring input of the protection relay is not exceeded This is always fulfilled when I1n Ikmax 100 Ikmax is the highest fault current The saturation of the CT protects the measuring circuit and the current input of the protection relay For that reason in practice even a few times smaller nominal primary current can be used than given by the formula Recommended start current settings If Ikmin is the ...

Page 1917: ...racy limit factor Fa should be chosen using the formula Fa 20 Current start value I1n The Current start value is the primary start current setting of the protection relay 12 1 1 3 Example for non directional overcurrent protection The following figure describes a typical medium voltage feeder The protection is implemented as three stage definite time non directional overcurrent protection Figure 1...

Page 1918: ...imary current is 1 percent and the limit of the phase displacement is 60 minutes The limit of the composite error at the rated accuracy limit primary current is 5 percent The approximate value of the accuracy limit factor Fa corresponding to the actual current transformer burden can be calculated on the basis of the rated accuracy limit factor Fn at the rated burden the rated burden Sn the interna...

Page 1919: ...o secure that the operate times of the protection relay comply with the retardation time The accuracy limit factors corresponding to the actual burden of the phase current transformer to be used in differential protection fulfill the requirement F K Ik T e a r dc T T m dc max ω 1 1 Equation 421 Ikmax The maximum through going fault current in I r at which the protection is not allowed to operate T...

Page 1920: ...etwork The protection must be stable also during re energization against a fault on the line In this case the existence of remanence is very probable It is assumed to be 40 percent here On the other hand the fault current is now smaller and since the ratio of the resistance and reactance is greater in this location having a full DC offset is not possible Furthermore the DC time constant Tdc of the...

Page 1921: ...actual accuracy limit factor due to oversizing the CT 1500 1000 30 45 In TR2PTDF and TR3PTDF it is important that the accuracy limit factors Fa of the phase current transformers at both sides correspond with each other that is the burdens of the current transformers on both sides are to be as equal as possible If high inrush or start currents with high DC components pass through the protected obje...

Page 1922: ...13 Protection relay s physical connections 13 1 Module diagrams Protection relay s physical connections 1MRS759142 F 1922 REX640 Technical Manual ...

Page 1923: ... CT5 for residual X1 X2 1 2 3 4 5 6 7 8 9 10 1 2 3 4 5 6 7 8 9 10 1 5A 1 5A 1 5A 0 2 1A S1 S2 P2 P1 S1 P1 P2 S2 Positive Load flow Direction AIM1001 n a da dn A n L1 L2 L3 L1 L2 L3 current only Figure 1020 AIM1001 module 1MRS759142 F Protection relay s physical connections REX640 Technical Manual 1923 ...

Page 1924: ... only c a A B C Figure 1021 AIM1001 module two phase to phase VTs The two phase to phase VT connection is often referred as open delta ANSI or as V IEC connection The relay measures all three phase to phase voltages using only two primary VTs The relay will calculate the phase to ground voltages internally with the assumption that the three phase system is balanced i e residual voltage is zero Pro...

Page 1925: ...CT5 N CT6 X1 X2 1 2 3 4 5 6 7 8 9 10 1 2 3 4 5 6 7 8 9 10 1 5A 1 5A 1 5A 1 5A S1 S2 P2 P1 S1 P1 P2 S2 Positive Load flow Direction AIM1002 n a da dn A n L1 L2 L3 L1 L2 L3 1 5A N Figure 1022 AIM1002 module 1MRS759142 F Protection relay s physical connections REX640 Technical Manual 1925 ...

Page 1926: ... Figure 1023 AIM1002 module two phase to phase VTs The two phase to phase VT connection is often referred as open delta ANSI or as V IEC connection The relay measures all three phase to phase voltages using only two primary VTs The relay will calculate the phase to ground voltages internally with the assumption that the three phase system is balanced i e residual voltage is zero Protection relay s...

Page 1927: ... 8 DFF Sensor I Sensor U DFF X2 4 5 7 8 DFF DFF X3 4 5 7 8 DFF DFF 3 4 Sensor I Sensor U Sensor I Sensor U s1 s2 s1 s2 s1 s2 for residual current only Figure 1024 SIM1901 module VT primary connection phase to earth 1MRS759142 F Protection relay s physical connections REX640 Technical Manual 1927 ...

Page 1928: ... 8 DFF Sensor I Sensor U DFF X2 DFF DFF X3 DFF DFF 3 4 Sensor I Sensor U Sensor I Sensor U s1 s2 s1 s2 s1 s2 for residual current only 4 5 7 8 4 5 7 8 Figure 1025 SIM1901 module VT primary connection phase to phase Protection relay s physical connections 1MRS759142 F 1928 REX640 Technical Manual ...

Page 1929: ... 8 DFF Sensor I Sensor U DFF X2 1 2 7 8 DFF DFF X3 1 2 7 8 DFF DFF 3 4 Sensor I Sensor U Sensor I Sensor U s1 s2 s1 s2 s1 s2 for residual current only Figure 1026 SIM1902 module VT primary connection phase to earth 1MRS759142 F Protection relay s physical connections REX640 Technical Manual 1929 ...

Page 1930: ... 8 DFF Sensor I Sensor U DFF X2 DFF DFF X3 DFF DFF 3 4 Sensor I Sensor U Sensor I Sensor U s1 s2 s1 s2 s1 s2 for residual current only 1 2 7 8 1 2 7 8 Figure 1027 SIM1902 module VT primary connection phase to phase Protection relay s physical connections 1MRS759142 F 1930 REX640 Technical Manual ...

Page 1931: ... 11 12 13 14 15 16 BI12 BI11 BI10 BI9 BI8 BI7 BI6 BI5 BI4 BI3 BI2 BI1 X2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 SO1 SO2 SO3 SO4 SO5 SO6 SO7 SO8 Figure 1028 BIO1001 BIO1003 modules 1MRS759142 F Protection relay s physical connections REX640 Technical Manual 1931 ...

Page 1932: ...8 BI7 BI6 BI5 BI4 BI3 BI2 BI1 X2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 SPO1 SPO3 SPO2 SPO4 SPO5 SPO6_TCS SPO7 SPO6 SPO8_TCS SPO8 I I Figure 1029 BIO1002 BIO1004 modules Protection relay s physical connections 1MRS759142 F 1932 REX640 Technical Manual ...

Page 1933: ...POSP2 X1 1 2 3 4 5 6 7 8 9 10 11 12 14 13 15 16 17 18 Uaux X2 1 2 3 IRF SO1 SO2 SSO1 SSO2 14 15 16 17 18 6 7 8 9 10 11 12 13 SO3 4 5 I I PO3_TCS I Figure 1030 PSM100x module 1MRS759142 F Protection relay s physical connections REX640 Technical Manual 1933 ...

Page 1934: ...TD2 10 11 12 Ref RTD3 13 14 15 Ref RTD4 16 17 18 Ref RTD5 1 2 3 Ref RTD6 4 5 6 Ref RTD7 7 8 9 Ref RTD8 10 11 12 Ref RTD9 13 14 15 Ref RTD10 16 17 18 6 Figure 1031 RTD1001 module Protection relay s physical connections 1MRS759142 F 1934 REX640 Technical Manual ...

Page 1935: ... 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 Ref RTD1 Ref RTD2 mA mA2 mA mA3 mA mA4 mA mA5 mA mA6 13 14 15 BI3 BI2 BI1 BI4 BI7 BI6 BI5 BI8 BI11 BI10 BI9 BI12 Figure 1032 RTD1002 module 1MRS759142 F Protection relay s physical connections REX640 Technical Manual 1935 ...

Page 1936: ... sensor input 1 Light sensor input 2 Light sensor input 3 Light sensor input 4 ARC1001 Slot A1 Slot A1 Slot A1 Slot A1 Figure 1033 Arc module Protection relay s physical connections 1MRS759142 F 1936 REX640 Technical Manual ...

Page 1937: ...Port Type Description X0 RJ 45 HMI X1 RJ 45 or LC Ethernet LAN A X2 RJ 45 or LC Ethernet LAN B X3 RJ 45 or LC Ethernet Interlink X6 SFP LC Protection communication 1 X7 FO ST Serial communication X8 TP 2 Serial communication IRIG B 1 If a galvanic pilot wire is used as the protection communication link the pilot wire modem RPW600 is required A single mode SFP transceiver and corresponding fiber op...

Page 1938: ...hardware module in Slot A1 The module supports connection of up to four sensors The sensors can be lens or loop types or a free mixture X11 X12 X13 X14 Light sensor input 1 Light sensor input 2 Light sensor input 3 Light sensor input 4 ARC1001 Slot A1 Slot A1 Slot A1 Slot A1 Figure 1035 ARC module The ARCSARC function must be instantiated in the application configuration to enable the sensor input...

Page 1939: ...r inputs Instance Sensor input activation ARCSARC1 Light sensor input 1 ARCSARC2 Light sensor input 2 ARCSARC3 Light sensor input 3 ARCSARC4 Light sensor input 4 1MRS759142 F Protection relay s physical connections REX640 Technical Manual 1939 ...

Page 1940: ... PSM1002 PSM1003 Nominal auxiliary voltage Un 24 30 48 60 V DC 100 110 120 220 240 V AC 50 and 60 Hz 110 125 V DC 48 60 110 125 220 250 V DC Maximum interrup tion time in the auxil iary DC voltage with out resetting the re lay 50 ms at Un Auxiliary voltage var iation 50 120 of Un 12 72 V DC 38 110 of Un 38 264 V AC 70 120 of Un 77 150 V DC Table continues on the next page 1 The HMI display element...

Page 1941: ... 24 48 60 110 125 220 250 V DC Auxiliary voltage variation 38 110 of Un 38 264 V AC 80 120 of Un 19 2 300 V DC Start up threshold 19 2 V DC 24 V DC 80 Burden of auxiliary voltage supply under qui escent Pq operating condition DC 6 0 W nominal 14 0 W max AC 7 0 W nominal 12 0 W max Ripple in the DC auxiliary voltage Max 15 of the DC value at frequency of 100 Hz Fuse type T3 15A 250V Table 1667 Ener...

Page 1942: ...mpedance at 50 60Hz 2 MΩ Voltage sensor input Rated secondary voltage 346 mV 2339 mV 7 Continuous voltage withstand 50 V Input impedance at 50 60Hz 2 MΩ Table 1670 Binary inputs Description Value Operating range 20 of the rated voltage Rated voltage 24 250 V DC Current drain 1 6 1 9 mA Power consumption 31 0 570 0 mW Table continues on the next page 3 Equals the current range of 40 4000 A with 80A...

Page 1943: ...s At the same time the threshold should be set so that the correct operation is not jeopardized in case of undervoltage of the auxiliary voltage Table 1671 RTD mA inputs and mA outputs Description Value RTD inputs Supported RTD sen sors 100 Ω platinum 250 Ω platinum 100 Ω nickel 120 Ω nickel 250 Ω nickel TCR 0 00385 DIN 43760 TCR 0 00385 TCR 0 00618 DIN 43760 TCR 0 00618 TCR 0 00618 Supported resi...

Page 1944: ...age 250 V AC DC Maximum continuous burden resistive load AC 2000 VA Continuous contact carry 8 A Make and carry for 3 0 s 15 A Make and carry for 0 5 s 30 A Breaking capacity when the control circuit time constant L R 40 ms at 48 110 220 V DC 5 A 3 A 1 A Minimum contact load 100 mA at 24 V AC DC Table 1674 Static signal output SSO relays Description Value Rated voltage 250 V AC DC Maximum continuo...

Page 1945: ...C DC 15 20 V Table 1676 Static power output SPO relays Description Value Rated voltage 250 V DC Maximum continuous burden resistive load DC 2000 VA Continuous contact carry 5 A 60 s 5 A continuous one output active at a time per module 1 A continuous multiple outputs simultane ously active in the same module Make and carry for 0 2 s 30 A Breaking capacity when the control circuit time constant L R...

Page 1946: ...requency Average processing delay time 1800 1520 Maximum processing delay time 2000 1720 Table 1681 Protection communication link connector X6 Connector Part number3 Fiber type Reach1 Wavelength Permitted path attenuation2 LC SFP 2RCA045621 MM 62 5 125 or 50 125 μm 2 km 1310 nm 8 dB LC SFP 2RCA045622 SM 9 125 μm 20 km 1310 nm 13 dB LC SFP 2RCA045623 SM 9 125 μm 50 km 1310 nm 26 dB 1 Maximum length...

Page 1947: ...ription Value Front connector side IP 20 with ring lug signal connectors IP 00 or IP 10 depending on wiring Top and bottom IP 30 Rear IP 40 Table 1685 Degree of protection of the HMI Description Value Front IP 54 Other sides IP 20 Table 1686 Environmental conditions Description Value Operating temperature range 25 55ºC continuous Short time service temperature range 40 85ºC 16 h 5 6 Relative humid...

Page 1948: ...Description Value Altitude Up to 2000 m Transport and storage temperature range 40 85ºC Technical data 1MRS759142 F 1948 REX640 Technical Manual ...

Page 1949: ...Hz 80 MHz 10 V m rms f 80 2700 MHz 10 V m f 900 MHz 20 V m rms f 80 1000 MHz IEC 61000 4 6 IEC 60255 26 class III IEC 61000 4 3 IEC 60255 26 class III ENV 50204 IEC 60255 26 class III IEEE C37 90 2 2004 Fast transient disturbance test Communication Other ports 2 kV 4 kV IEC 61000 4 4 IEC 60255 26 IEEE C37 90 1 2012 Surge immunity test Communication Other ports 1 kV line to earth 4 kV line to earth...

Page 1950: ...peak 66 dB µV average 73 dB µV quasi peak 60 dB µV average 40 dB µV m quasi peak measured at 10 m distance 47 dB µV m quasi peak measured at 10 m distance 76 dB µV m peak 56 dB µV m average measured at 3 m distance 80 dB µV m peak 60 dB µV m average measured at 3 m distance EN 55011 class A IEC 60255 26 CISPR 11 CISPR 12 Table 1688 Safety related tests Description Type test value Reference Overvol...

Page 1951: ...1689 Mechanical tests Description Requirement Reference Vibration tests sinusoidal Class 2 IEC 60068 2 6 test Fc IEC 60255 21 1 Shock and bump test Class 2 IEC 60068 2 27 test Ea shock IEC 60068 2 29 test Eb bump IEC 60255 21 2 Table 1690 Environmental tests Description Type test value Reference Dry heat test 96 h at 55 C 16 h at 85 C 1 IEC 60068 2 2 Dry cold test 96 h at 25 C 16 h at 40 C IEC 600...

Page 1952: ...ective 2006 95 EC Standard EN 60255 27 2014 EN 60255 1 2009 Table 1692 EMC compliance Description Reference EMC directive 2014 30 EU Standard EN 60255 26 2013 Table 1693 RoHS compliance Description Complies with RoHS Directive 2011 65 EU Protection relay and functionality tests 1MRS759142 F 1952 REX640 Technical Manual ...

Page 1953: ...il directive 2004 108 EC EU directive 2002 96 EC 175 IEC 60255 Low voltage directive 2006 95 EC IEC 61850 BS EN 60255 26 2013 BS EN 61000 6 2 2005 BS EN 61000 6 4 2019 BS EN 60255 1 2010 BS EN 60255 27 2014 1MRS759142 F Applicable standards and regulations REX640 Technical Manual 1953 ...

Page 1954: ... that is backward compatible with CAT 5 5e and CAT 3 cable standards CB Circuit breaker CBB Cycle building block CBCT Core balance current transformer CBFP Circuit breaker failure protection COM600S Substation Management Unit An all in one communication gateway au tomation platform and user interface solution for utility and industrial distribution substations COMTRADE Common format for transient ...

Page 1955: ... fault criteria GIS 1 Gas insulated switchgear 2 Geoinformation systems GND Ground earth GNSS Global navigation satellite systems GOOSE Generic object oriented substation event GPS Global positioning system HF High frequency HMI Human machine interface HSR High availability seamless redundancy HTTPS Hypertext transfer protocol secure HV High voltage IDMT Inverse definite minimum time IEC Internati...

Page 1956: ... Logical node IEC61850 LOG Loss of grid LOM Loss of mains LV Low voltage M F Master Follower MAC Media access control MCB Miniature circuit breaker MCC Minimizing circulating current MM 1 Multimode 2 Multimode optical fiber MMS 1 Manufacturing message specification 2 Metering management system Modbus A serial communication protocol developed by the Modicon company in 1979 Originally used for commu...

Page 1957: ...e two times the set start value PGU Power generating unit PLC Programmable logic controller PMS Power management system PO Power output PODP Power output double pole POSP Power output single pole POTT Permissive overreach transfer trip PPS Pulse per second PRP Parallel redundancy protocol PST Parameter setting tool PTP Precision time protocol PUTT Permissive underreach transfer trip RAM Random acc...

Page 1958: ...ocol SOTF Switch onto fault SPO Static power output SSO Static signal output ST Connector type for glass fiber cable TCP Transmission control protocol TCS Trip circuit supervision TP Disturbance data recorded with or without trip bit Tx Transmit Transmitted UART Universal asynchronous receiver transmitter UDP User datagram protocol USB Universal serial bus UTC Coordinated universal time VDR Voltag...

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Page 1960: ...voltage www abb com relion www abb com substationautomation ABB Distribution Solutions Digital Substation Products P O Box 699 FI 65101 VAASA Finland Phone 358 10 22 11 1MRS759142 F Copyright 2023 ABB All rights reserved ...

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