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ABB REG670 2.0 IEC, Commissioning Manual

The ABB REG670 2.0 IEC is an advanced protection and control relay that ensures reliable and safe operations in electrical networks. This versatile product comes with a comprehensive Commissioning Manual, available for free download at manualshive.com. Gain a deeper understanding of this cutting-edge technology and unleash its full potential.

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Basic IED functions........................................................................ 235

Parameter setting group handling SETGRPS........................... 235

Verifying the settings............................................................ 235
Completing the test.............................................................. 236

Exit test mode.................................................................................236

Section 13 Checking the directionality........................................... 237

Overview.........................................................................................237
Testing the directionality of the distance protection........................237

Section 14 Commissioning and maintenance of the fault

clearing system............................................................ 241

Commissioning tests...................................................................... 241
Periodic maintenance tests............................................................ 241

Visual inspection........................................................................242
Maintenance tests..................................................................... 242

Preparation...........................................................................242
Recording............................................................................. 243
Secondary injection.............................................................. 243
Alarm test............................................................................. 243
Self supervision check..........................................................243
Trip circuit check.................................................................. 243
Measurement of service currents......................................... 244
Restoring.............................................................................. 245

Section 15 Troubleshooting............................................................247

Checking the self supervision signals.............................................247

Checking the self supervision function...................................... 247

Determine the cause of an internal failure............................247

Self supervision HMI data..........................................................247

General IED status............................................................... 247

Fault tracing....................................................................................248

Internal fault indications.............................................................248
Using front-connected PC......................................................... 249

Repair instruction............................................................................250
Repair support................................................................................ 252
Maintenance................................................................................... 252

Section 16 Glossary....................................................................... 253

Table of contents

Generator protection REG670 2.0 IEC

9

Commissioning manual

Summary of Contents for REG670 2.0 IEC

Page 1: ...Relion 670 series Generator protection REG670 2 0 IEC Commissioning manual ...

Page 2: ......

Page 3: ...Document ID 1MRK502053 UEN Issued July 2016 Revision B Product version 2 0 Copyright 2014 ABB All rights reserved ...

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

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

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

Page 7: ...29 Back up protection functions 30 Control and monitoring functions 31 Communication 35 Basic IED functions 37 Section 4 Starting up 39 Factory and site acceptance testing 39 Commissioning checklist 39 Checking the power supply 40 Energizing the IED 40 Checking the IED operation 40 IED start up sequence 41 Energizing REX060 41 REX060 start up sequence 41 Setting up communication between PCM600 and...

Page 8: ...to file 68 Section 7 Calibrating injection based 100 stator earth fault protection 71 Commissioning process 71 Commissioning tool ICT 71 Launching injection commissioning tool ICT 74 Performing calibration 75 Acquiring references 77 Verifying calibration 79 Auditing 80 Editing features in graph 82 Logging measurements to file 83 Section 8 Establishing connection and verifying the SPA IEC communica...

Page 9: ...tested 99 Verifying analog primary and secondary measurement 100 Testing the protection functionality 101 Section 12 Testing functionality by secondary injection 103 Testing disturbance report 103 Introduction 103 Disturbance report settings 103 Disturbance recorder DR 103 Event recorder ER and Event list EL 104 Identifying the function to test in the technical reference manual 105 Differential pr...

Page 10: ...e settings 119 Completing the test 122 Out of step protection OOSPPAM 122 Verifying the settings 123 Test of point RE RFwdR XFwdX 127 Test of the boundary between zone 1 and zone 2 which is defined by the parameter ReachZ1 131 Test of the point SE RRvsR XRvsX 135 Loss of excitation LEXPDIS 140 Verifying the settings 140 Completing the test 142 Under impedance protection for Generator ZGVPDIS 142 V...

Page 11: ...tion phase segregated activation and output CCRBRF 160 Checking the phase current operate value IP 160 Checking the residual earth fault current operate value IN set below IP 161 Checking the re trip and back up times 161 Verifying the re trip mode 161 Verifying the back up trip mode 162 Verifying instantaneous back up trip at CB faulty condition 163 Verifying the case RetripMode Contact 163 Verif...

Page 12: ...p residual overvoltage protection ROV2PTOV 179 Verifying the settings 179 Completing the test 180 Overexcitation protection OEXPVPH 180 Verifying the settings 180 Completing the test 181 Voltage differential protection VDCPTOV 181 Check of undervoltage levels 181 Check of voltage differential trip and alarm levels 183 Check of trip and trip reset timers 184 Final adjustment of compensation for VT ...

Page 13: ... Checking that the binary inputs and outputs operate as expected 197 Measuring the operate value for the negative sequence function 198 Measuring the operate value for the zero sequence function 199 Measuring the operate value for the dead line detection function 200 Checking the operation of the du dt and di dt based function 200 Completing the test 201 Fuse failure supervision VDSPVC 201 Complet...

Page 14: ...n SSIMG 227 Testing the liquid medium supervision for alarm and lock out conditions 227 Completing the test 227 Liquid medium supervision SSIML 227 Testing the liquid medium supervision for alarm and lock out conditions 228 Completing the test 228 Breaker monitoring SSCBR 228 Verifying the settings 229 Completing the test 230 Event function EVENT 231 Limit counter L4UFCNT 231 Completing the test 2...

Page 15: ...42 Preparation 242 Recording 243 Secondary injection 243 Alarm test 243 Self supervision check 243 Trip circuit check 243 Measurement of service currents 244 Restoring 245 Section 15 Troubleshooting 247 Checking the self supervision signals 247 Checking the self supervision function 247 Determine the cause of an internal failure 247 Self supervision HMI data 247 General IED status 247 Fault tracin...

Page 16: ...10 ...

Page 17: ...The chapters are organized in the chronological order in which the IED should be commissioned The relevant procedures may be followed also during the service and maintenance activities 1 2 Intended audience This manual addresses the personnel responsible for commissioning maintenance and taking the IED in and out of normal service The commissioning personnel must have a basic knowledge of handling...

Page 18: ... IEDs to the project structure The manual also recommends a sequence for the engineering of protection and control functions LHMI functions as well as communication engineering for IEC 60870 5 103 IEC 61850 and DNP3 The installation manual contains instructions on how to install the IED The manual provides procedures for mechanical and electrical installation The chapters are organized in the chro...

Page 19: ...ogic diagrams input and output signals setting parameters and technical data sorted per function The manual can be used as a technical reference during the engineering phase installation and commissioning phase and during normal service The communication protocol manual describes the communication protocols supported by the IED The manual concentrates on the vendor specific implementations The poi...

Page 20: ...ion 2 1MRK 511 303 UEN Communication protocol manual LON 1MRK 511 305 UEN Communication protocol manual SPA 1MRK 511 306 UEN Accessories guide 1MRK 514 012 BEN Cyber security deployment guideline 1MRK 511 309 UEN Connection and Installation components 1MRK 513 003 BEN Test system COMBITEST 1MRK 512 001 BEN 1 4 Document symbols and conventions 1 4 1 Symbols The electrical warning icon indicates the...

Page 21: ...itions of important terms Push button navigation in the LHMI menu structure is presented by using the push button icons For example to navigate between the options use and HMI menu paths are presented in bold For example select Main menu Settings LHMI messages are shown in Courier font For example to save the changes in non volatile memory select Yes and press Parameter names are shown in italics ...

Page 22: ...ping Table 1 IEC 61850 edition 1 edition 2 mapping Function block name Edition 1 logical nodes Edition 2 logical nodes AEGPVOC AEGGAPC AEGPVOC AGSAL AGSAL SECLLN0 AGSAL ALMCALH ALMCALH ALMCALH ALTIM ALTIM ALTMS ALTMS ALTRK ALTRK BCZSPDIF BCZSPDIF BCZSPDIF BCZTPDIF BCZTPDIF BCZTPDIF BDCGAPC SWSGGIO BBCSWI BDCGAPC BRCPTOC BRCPTOC BRCPTOC BRPTOC BRPTOC BRPTOC BTIGAPC B16IFCVI BTIGAPC BUSPTRC_B1 BUSPT...

Page 23: ...USPTRC BUSPTRC BUTPTRC_B1 BUTPTRC BBTPLLN0 BUTPTRC BUTPTRC_B2 BUTPTRC BUTPTRC BUTPTRC_B3 BUTPTRC BUTPTRC BUTPTRC_B4 BUTPTRC BUTPTRC BUTPTRC_B5 BUTPTRC BUTPTRC BUTPTRC_B6 BUTPTRC BUTPTRC BUTPTRC_B7 BUTPTRC BUTPTRC BUTPTRC_B8 BUTPTRC BUTPTRC BZISGGIO BZISGGIO BZISGAPC BZITGGIO BZITGGIO BZITGAPC BZNSPDIF_A BZNSPDIF BZASGAPC BZASPDIF BZNSGAPC BZNSPDIF BZNSPDIF_B BZNSPDIF BZBSGAPC BZBSPDIF BZNSGAPC BZN...

Page 24: ... PH1PTRC GF2MMXN GF2PHAR GF2PTOV GF2PTUC GF2PTUV GF2PVOC PH1PTRC CVMMXN CVMMXN CVMMXN D2PTOC D2LLN0 D2PTOC PH1PTRC D2PTOC PH1PTRC DPGAPC DPGGIO DPGAPC DRPRDRE DRPRDRE DRPRDRE ECPSCH ECPSCH ECPSCH ECRWPSCH ECRWPSCH ECRWPSCH EF2PTOC EF2LLN0 EF2PTRC EF2RDIR GEN2PHAR PH1PTOC EF2PTRC EF2RDIR GEN2PHAR PH1PTOC EF4PTOC EF4LLN0 EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EF4PTRC EF4RDIR GEN4PHAR PH1PTOC EFPIOC EFPIOC...

Page 25: ...HZPDIF HZPDIF HZPDIF INDCALCH INDCALH INDCALH ITBGAPC IB16FCVB ITBGAPC L3CPDIF L3CPDIF L3CGAPC L3CPDIF L3CPHAR L3CPTRC L4UFCNT L4UFCNT L4UFCNT L6CPDIF L6CPDIF L6CGAPC L6CPDIF L6CPHAR L6CPTRC LAPPGAPC LAPPLLN0 LAPPPDUP LAPPPUPF LAPPPDUP LAPPPUPF LCCRPTRC LCCRPTRC LCCRPTRC LCNSPTOC LCNSPTOC LCNSPTOC LCNSPTOV LCNSPTOV LCNSPTOV LCP3PTOC LCP3PTOC LCP3PTOC LCP3PTUC LCP3PTUC LCP3PTUC LCPTTR LCPTTR LCPTTR...

Page 26: ...4RDIR GEN4PHAR PH1PTOC EF4PTRC EF4RDIR PH1PTOC O2RWPTOV GEN2LLN0 O2RWPTOV PH1PTRC O2RWPTOV PH1PTRC OC4PTOC OC4LLN0 GEN4PHAR PH3PTOC PH3PTRC GEN4PHAR PH3PTOC PH3PTRC OEXPVPH OEXPVPH OEXPVPH OOSPPAM OOSPPAM OOSPPAM OOSPTRC OV2PTOV GEN2LLN0 OV2PTOV PH1PTRC OV2PTOV PH1PTRC PAPGAPC PAPGAPC PAPGAPC PCFCNT PCGGIO PCFCNT PH4SPTOC GEN4PHAR OCNDLLN0 PH1BPTOC PH1PTRC GEN4PHAR PH1BPTOC PH1PTRC PHPIOC PHPIOC P...

Page 27: ...YN MAN1RSYN SYNRSYN AUT1RSYN MAN1RSYN SYNRSYN SINGLELCCH SCHLCCH SLGAPC SLGGIO SLGAPC SMBRREC SMBRREC SMBRREC SMPPTRC SMPPTRC SMPPTRC SP16GAPC SP16GGIO SP16GAPC SPC8GAPC SPC8GGIO SPC8GAPC SPGAPC SPGGIO SPGAPC SSCBR SSCBR SSCBR SSIMG SSIMG SSIMG SSIML SSIML SSIML STBPTOC STBPTOC BBPMSS STBPTOC STEFPHIZ STEFPHIZ STEFPHIZ STTIPHIZ STTIPHIZ STTIPHIZ SXCBR SXCBR SXCBR SXSWI SXSWI SXSWI T2WPDIF T2WPDIF ...

Page 28: ...PVC VMMXU VMMXU VMMXU VMSQI VMSQI VMSQI VNMMXU VNMMXU VNMMXU VRPVOC VRLLN0 PH1PTRC PH1PTUV VRPVOC PH1PTRC PH1PTUV VRPVOC VSGAPC VSGGIO VSGAPC WRNCALH WRNCALH WRNCALH ZC1PPSCH ZPCPSCH ZPCPSCH ZC1WPSCH ZPCWPSCH ZPCWPSCH ZCLCPSCH ZCLCPLAL ZCLCPSCH ZCPSCH ZCPSCH ZCPSCH ZCRWPSCH ZCRWPSCH ZCRWPSCH ZCVPSOF ZCVPSOF ZCVPSOF ZGVPDIS ZGVLLN0 PH1PTRC ZGVPDIS ZGVPTUV PH1PTRC ZGVPDIS ZGVPTUV ZMCAPDIS ZMCAPDIS Z...

Page 29: ...S ZMFPTRC ZMMMXU ZMHPDIS ZMHPDIS ZMHPDIS ZMMAPDIS ZMMAPDIS ZMMAPDIS ZMMPDIS ZMMPDIS ZMMPDIS ZMQAPDIS ZMQAPDIS ZMQAPDIS ZMQPDIS ZMQPDIS ZMQPDIS ZMRAPDIS ZMRAPDIS ZMRAPDIS ZMRPDIS ZMRPDIS ZMRPDIS ZMRPSB ZMRPSB ZMRPSB ZSMGAPC ZSMGAPC ZSMGAPC 1MRK502053 UEN B Section 1 Introduction Generator protection REG670 2 0 IEC 23 Commissioning manual ...

Page 30: ...24 ...

Page 31: ...re 2 2 Warnings Observe the warnings during all types of work related to the product Only electrically skilled persons with the proper authorization and knowledge of any safety hazards are allowed to carry out the electrical installation National and local electrical safety regulations must always be followed Working in a high voltage environment requires serious approach to avoid human injuries a...

Page 32: ... configuration This is class 1 equipment that shall be earthed Never disconnect the secondary connection of current transformer circuit without short circuiting the transformer s secondary winding Operating a current transformer with the secondary winding open will cause a massive potential build up that may damage the transformer and may cause injuries to humans Never remove any screw from a powe...

Page 33: ... earth when replacing modules Electrostatic discharge ESD may damage the module and IED circuitry Take care to avoid electrical shock during installation and commissioning Changing the active setting group will inevitably change the IEDs operation Be careful and check regulations before making the change Avoid touching the enclosure of the coupling capacitor REX061 unit and the shunt resistor REX0...

Page 34: ...ve the maximum allowed continuous current for the different current transformer inputs of the IED See technical data Section 2 1MRK502053 UEN B Safety information 28 Generator protection REG670 2 0 IEC Commissioning manual ...

Page 35: ...e protection ZMHPDIS 21 Fullscheme distance protection mho characteristic 0 4 3 3 3 ZDMRDIR 21D Directional impedance element for mho characteristic 0 2 1 1 1 ZDARDIR Additional distance protection directional function for earth faults ZMFPDIS 21 High speed distance protection 0 1 ZMFCPDIS 21 High speed distance protection for series compensated lines 0 1 PSPPPAM 78 Pole slip out of step protectio...

Page 36: ...F Breaker failure protection 0 4 2 4 4 STBPTOC 50STB Stub protection CCPDSC 52PD Pole discordance protection 0 4 2 2 2 GUPPDUP 37 Directional underpower protection 0 4 2 4 4 GOPPDOP 32 Directional overpower protection 0 4 2 4 4 BRCPTOC 46 Broken conductor check NS2PTOC 46I2 Negative sequence time overcurrent protection for machines 0 2 1 1 1 AEGPVOC 50AE Accidental energizing protection for synchr...

Page 37: ...quency time accumulation protection 0 12 12 E03 12 E03 12 E03 Multipurpose protection CVGAPC General current and voltage protection 1 12 6 6 6 General calculation SMAIHPAC Multipurpose filter 0 6 1 67 requires voltage 2 67N requires voltage 3 3 Control and monitoring functions IEC 61850 ANSI Function description Generator REG670 REG670 A20 REG670 B30 REG670 C30 Control SESRSYN 25 Synchrocheck ener...

Page 38: ...SINGLECMD Single command 16 signals 4 4 4 4 I103CMD Function commands for IEC 60870 5 103 1 1 1 1 I103GENCMD Function commands generic for IEC 60870 5 103 50 50 50 50 I103POSCMD IED commands with position and select for IEC 60870 5 103 50 50 50 50 I103IEDCMD IED commands for IEC 60870 5 103 1 1 1 1 I103USRCMD Function commands user defined for IEC 60870 5 103 1 1 1 1 Secondary system supervision C...

Page 39: ...sion 18 18 18 18 BTIGAPC Boolean 16 to Integer conversion with Logic Node representation 16 16 16 16 IB16 Integer to Boolean 16 conversion 18 18 18 18 ITBGAPC Integer to Boolean 16 conversion with Logic Node representation 16 16 16 16 TIGAPC Delay on timer with input signal integration 30 30 30 30 TEIGAPC Elapsed time integrator with limit transgression and overflow supervision 12 12 12 12 Monitor...

Page 40: ...cuit breaker monitoring 0 4 2 M12 4 M14 4 M14 I103MEAS Measurands for IEC 60870 5 103 1 1 1 1 I103MEASUSR Measurands user defined signals for IEC 60870 5 103 3 3 3 3 I103AR Function status auto recloser for IEC 60870 5 103 1 1 1 1 I103EF Function status earth fault for IEC 60870 5 103 1 1 1 1 I103FLTPROT Function status fault protection for IEC 60870 5 103 1 1 1 1 I103IED IED status for IEC 60870 ...

Page 41: ... CHSEROPT DNP3 0 for TCP IP and EIA 485 communication protocol 1 1 1 1 MST1TCP MST2TCP MST3TCP MST4TCP DNP3 0 for serial communication protocol 1 1 1 1 DNPFREC DNP3 0 fault records for TCP IP and EIA 485 communication protocol 1 1 1 1 IEC61850 8 1 Parameter setting function for IEC 61850 1 1 1 1 GOOSEINTLKR CV Horizontal communication via GOOSE for interlocking 59 59 59 59 GOOSEBINRCV Goose binary...

Page 42: ... 1 PCMACCS IED Configuration Protocol 1 1 1 1 SECALARM Component for mapping security events on protocols such as DNP3 and IEC103 1 1 1 1 FSTACCS Field service tool access via SPA protocol over ethernet communication 1 1 1 1 ACTIVLOG Activity logging parameters 1 1 1 1 ALTRK Service Tracking 1 1 1 1 SINGLELCCH Single ethernet port link status 1 1 1 1 PRPSTATUS Dual ethernet port link status 1 1 1 ...

Page 43: ...puts SMBO Signal matrix for binary outputs SMMI Signal matrix for mA inputs SMAI1 SMAI20 Signal matrix for analog inputs 3PHSUM Summation block 3 phase ATHSTAT Authority status ATHCHCK Authority check AUTHMAN Authority management FTPACCS FTP access with password SPACOMMMAP SPA communication mapping SPATD Date and time via SPA protocol DOSFRNT Denial of service frame rate control for front port DOS...

Page 44: ...PGENTCP DNP3 0 communication general TCP protocol CHSEROPT DNP3 0 for TCP IP and EIA 485 communication protocol MSTSER DNP3 0 for serial communication protocol OPTICAL103 IEC 60870 5 103 Optical serial communication RS485103 IEC 60870 5 103 serial communication for RS485 IEC61850 8 1 Parameter setting function for IEC 61850 HORZCOMM Network variables via LON LONSPA SPA communication protocol LEDGE...

Page 45: ...Site acceptance testing SAT or commissioning testing is typically done to verify that the installed IED is correctly set and connected to the power system SAT requires that the acceptance testing has been performed and that the application configuration is verified Maintenance testing is a periodic verification that the IED is healthy and has correct settings depending on changes in the power syst...

Page 46: ...commissioning procedures Energize the power supply of the IED to start it up Keep the DC power supply on until the Root menu or the selected default screen is shown on the HMI before interrupting the DC power supply again The energization could be done in a number of ways from energizing a whole cubicle with many IEDs to energizing each single IED one by one If HW i e I O and or communication boar...

Page 47: ...and IED startup is displayed 3 The main menu is displayed A steady green light indicates a successful startup If the upper row in the window indicates Fail instead of Ready and the green LED flashes an internal failure in the IED has been detected See section Checking the self supervision function to investigate the fault 4 5 Energizing REX060 4 5 1 REX060 start up sequence When the injection unit...

Page 48: ...oject for each IED to match the IP addresses of the physical IEDs Setting up IP addresses The IP address and the corresponding mask must be set via the LHMI for each available Ethernet interface in the IED Each Ethernet interface has a default factory IP address when the IED is delivered This is not given when an additional Ethernet interface is installed or an interface is replaced The default IP...

Page 49: ...mple is taken from a Laptop with one Ethernet interface Administrator rights are required to change the PC communication setup Some PCs have the feature to automatically detect that Tx signals from the IED are received on the Tx pin on the PC Thus a straight standard Ethernet cable can be used 1 Select Search programs and files in the Start menu in Windows 1MRK502053 UEN B Section 4 Starting up Ge...

Page 50: ...0057 V1 EN Figure 4 Select Search programs and files 2 Type View network connections and click on the View network connections icon Section 4 1MRK502053 UEN B Starting up 44 Generator protection REG670 2 0 IEC Commissioning manual ...

Page 51: ... IEC13000059 1 en vsd IEC13000059 V1 EN Figure 6 Right click Local Area Connection and select Properties 4 Select the TCP IPv4 protocol from the list of configured components using this connection and click Properties 1MRK502053 UEN B Section 4 Starting up Generator protection REG670 2 0 IEC 45 Commissioning manual ...

Page 52: ...address and define IP address and Subnet mask if the front port is used and if the IP address is not set to be obtained automatically by the IED see Figure 8 The IP address must be different from the IP address chosen for the IED Section 4 1MRK502053 UEN B Starting up 46 Generator protection REG670 2 0 IEC Commissioning manual ...

Page 53: ... application configuration to the IED When writing a configuration to the IED with PCM600 the IED is automatically set in configuration mode When the IED is set in configuration mode all functions are blocked The red LED on the IED flashes and the green LED is lit while the IED is in the configuration mode When the configuration is written and completed the IED is automatically set into normal mod...

Page 54: ...p resistance is near the calculated value for maximum DC resistance perform a complete burden test CT excitation test in order to confirm that the current transformer is of the correct accuracy rating and that there are no shorted turns in the current transformer windings Manufacturer s design curves must be available for the current transformer to compare the actual results Earthing check of the ...

Page 55: ... secondary side 4 10 Using the RTXP test switch The RTXP test switch is designed to provide the means of safe testing of the IED This is achieved by the electromechanical design of the test switch and test plug handle When the test plug handle is inserted it first blocks the trip and alarm circuits then it short circuits the CT secondary circuit and opens the VT secondary circuits making the IED a...

Page 56: ...ding male connector Inserting anything else such as a measurement probe may damage the female connector and prevent a proper electrical contact between the printed circuit board and the external wiring connected to the screw terminal block 4 11 1 Binary input circuits Preferably disconnect the binary input connector from the binary input cards Check all connected signals so that both input level a...

Page 57: ...ace requirement of 180 mm for plastic fiber cables and 275 mm for glass fiber cables Check the allowed minimum bending radius from the optical cable manufacturer 1MRK502053 UEN B Section 4 Starting up Generator protection REG670 2 0 IEC 51 Commissioning manual ...

Page 58: ...52 ...

Page 59: ... be established before the settings can be written to the IED Make sure that the DC supply is not turned off when the IED saves the written configuration The IED uses a FLASH disk for storing configuration data and process data like counters object states Local Remote switch position etc Since FLASH memory is used measures have been taken in software to make sure that the FLASH disk is not worn ou...

Page 60: ...ter shall be set for every current transformer connected to the IED Table 3 CT configuration Parameter description Parameter name Range Default Rated CT primary current in A CT Prim Input from 0 to 99999 3000 This parameter defines the primary rated current of the CT For two set of CTs with ratio 1000 1 and 1000 5 this parameter is set to the same value of 1000 for both CT inputs The parameter CTS...

Page 61: ...al or module failure The error flag is also set when the physical I O module of the correct type is not detected in the connected slot 1MRK502053 UEN B Section 5 Configuring the IED and changing settings Generator protection REG670 2 0 IEC 55 Commissioning manual ...

Page 62: ...56 ...

Page 63: ...e and validating capabilities During installation commissioning and calibration ICT performs various tests to verify that the installation is acceptable and the calibration successful Besides carrying out the actual tests ICT also provides the commissioning engineer with tips if needed during the commissioning When ICT is started rotor earth fault protection is chosen There are five different part...

Page 64: ...tion session follows a scheme shown in the tool Calibration sequence 1 The injection must be activated and the rotor must be left with no impedance connected The ICT now makes consecutive measurements until the statistical error reaches an acceptable value This is graphically shown in a diagram The user stops the sequence by acceptance of the measurement The result is stored for later calculations...

Page 65: ... done For each operation state of interest a measurement is performed If the reference impedance differs from the first one calculated under the calibration session the new reference impedance is stored by the command Submit toParameter Setting If more than one reference impedance are to be used there must be a logic configured to detect such changes in the operation states that requires a change ...

Page 66: ...the injection unit REX060 If the voltage and or current level s frequencies are not reasonable or the ICT indicates other warnings abnormalities in the function status field verify that the HW connections are proper cables etc and selected gains and injection frequencyonthe REX060isproperlyselected Thenrepeatsteps3to6 Notethat the FreqInjected setting in Parameter setting for the specific function...

Page 67: ...d the stability region turned green select the Submit button ICT automatically shifts to the second calibration sub tab Step2 Calibration step 2 Stability region indicator bar IEC11000047 1 en vsd GUID 3C7F0567 2367 46E4 9606 FCFC7408DAA0 V1 EN Figure 12 ICT calibration tab 1 including the stability region indicator bar 5 Attach an 10kΩ known fault 10kΩ resistance to ground 6 Type 10000 in the rea...

Page 68: ... Calibration result field that all tests have been passed 12 1 If a failure is indicated during one or more check s follow the instructions tips provided by the ICT in the Calibration result field 12 2 If these tips do not solve the issue then contact ABB Support IEC11000221 1 en vsd IEC11000221 V1 EN Figure 13 ICT calibration tab 4 13 Before proceeding any further make sure that you have removed ...

Page 69: ...select the Commissioning tab 3 In the Reference impedance selection drop down menu select Reference 2 4 To start reading the measurements click the Start reading from IED button in the ICT toolbar ICT starts to read the selected viewed quantity from IED and plots values on the X Y graph Measured absolute impedance standard deviation Measured absolute impedance Floating average of the measured abso...

Page 70: ...ter the calibration is performed it is appropriate to verify that known faults are measured as expected and that the function is indicating trips and alarms when it should in other words that the calibration was successful For this purpose the monitoring feature can be used 1 In the ICT toolbar select the fourth tab Monitoring Logger feature Currently measured impedance and its average Selectable ...

Page 71: ...tively small You should be able to measure approximately 10kΩ here If you choose to view fault conductance the measurement corresponds to approximately 1 10 4 Mho 7 Apply another known fault say 1kΏ and verify that it is measured correctly 8 When you are completely sure that the function measures correctly stop the measurements and remove any applied faults Previously it was verified that the func...

Page 72: ...report 3 View reports in one of the following ways In the short cut menu right click and select View report Click the View report button in the upper right corner of the auditing screen Double click a report record 4 Delete reports in one of the following ways In the short cut menu right click and select Delete report Click the Delete report button in the upper right corner of the auditing screen ...

Page 73: ...ph You can do the following operations on the graph during calibration commissioning and monitoring Zoom in Zoom out Cancel zoom Enable X zooming Enable Y zooming 1 Zoom in one of the following ways Right click a graph and select Zoom in or Zoom out in the shortcut menu IEC11000051 1 en vsd GUID 3F080E48 8B77 48A0 8283 89511E1AE50B V1 EN Figure 17 Zooming via the shortcut menu Use the mouse to zoo...

Page 74: ...ements to file In addition to viewing online plotted data under the Monitoring tab it is also possible to log quantities to a file tabbed text file that can be viewed in the graph Besides this voltage levels measured by the function and also error codes are logged This file can then be imported to other tools for deeper analysis when needed The logger feature is available on the lower right corner...

Page 75: ...efault value is 1 hour The period can be adjusted before the logging is started if needed 5 The logging can be stopped by selecting the Stop button 6 You can open the file in notepad or MS Excel 1MRK502053 UEN B Section 6 Calibrating injection based sensitive rotor earth fault protection Generator protection REG670 2 0 IEC 69 Commissioning manual ...

Page 76: ...70 ...

Page 77: ... validating capabilities During installation commissioning and calibration ICT performs various tests to verify that the installation is acceptable and the calibration successful Besides carrying out the actual tests ICT also provides the commissioning engineer with tips if such are needed during the commissioning When ICT is started 100 stator earth fault protection is chosen There are five diffe...

Page 78: ... any other principles of injection with LV neutral point resistor connected via DT or injection via open delta connected VT group on the generator terminal etc Uinj RN Cstat Uinj RN Cstat Uinj RN Cstat Rtest Step 1 Step 2 Step 3 Iinj Iinj Iinj a b a b a b IEC11000044 1 en vsd GUID 9E470F57 D670 430C BD27 CBF11AF92D1E V1 EN Figure 19 Different steps at calibration measurements For other injection p...

Page 79: ... the beginning or other problems due to the installation or calibration procedure Now the reference impedance is derived for one operational state It might be necessary to make measurements to derive reference impedance for other operational cases For information on this see Commissioning below Commissioning There is a possibility to have up to five different reference impedances The need to chang...

Page 80: ...hange of reference impedance is required Auditing In the auditing part calibration and commissioning reports are made 7 3 Launching injection commissioning tool ICT 1 To launch the Injection commissioning tool ICT right click REG670 in the PCM plant structure and select the Injection commissioning 2 In the ICT toolbar select the 100 Stator Earth Fault function Function selection dropdown menu Butt...

Page 81: ...equency on the REX060 HMI for that function IEC11000045 1 en vsd Frequency found by the function Voltage and current signal staus and TRIP indication Ffunction status field Errors and abnormalities are displayed in order to simplify trouble shooting GUID 84947C77 215F 4007 AAC0 9433B8444396 V1 EN Figure 21 ICT signals and function indication panel 9 When you are ready to perform calibration select...

Page 82: ...again wait until the stability criteria is fulfilled then select the Submit button ICT automatically shifts to the third calibration tab Step3 Calibration step 3 9 Remove the known fault resistance attached earlier and apply a short circuit instead 10 In the ICT toolbar select the Start reading from IED button 11 When the stability criteria are fulfilled select the Submit button once again ICT aut...

Page 83: ...mpedance reference requires logic outside the injection function Therefore changing switching impedance reference is not described here but in a separate application note 1MRG005030 Application example for injection based 100 Stator EF and Sensitive Rotor EF protection The injection commissioning tool ICT helps the commissioning engineer to acquire additional references for different conditions of...

Page 84: ...ng the standard deviation of the measured impedance the commissioning engineer can decide if the impedance of the generator is stable settled and also if the average impedance is based on enough values so that statistically the signal noise is filtered out This results in a fairly accurate impedance measurement which can be used as an alternative reference 5 Click the Select button when the standa...

Page 85: ...ontinuously plotting values on the graph with one second interval select Start readings from IED By default the measured absolute impedance is plotted however there are several items that can be viewed when monitoring To see these select the available quantities under the Viewed quantity drop down menu under the Monitoring tab 4 Observe the fault conductance while applying known faults Both the ca...

Page 86: ...ing Besides measuring the fault size a trip indication is required when a large fault is measured to prevent that a damage to the generator occurs To allow the specific function to issue a trip indication it must first be enabled 8 1 Select the Enable Function Tripping button in the ICT toolbar 8 2 Choose Yes in the pop up message ICT now writes this to IED 8 3 By default the trip level is set to ...

Page 87: ...port button in the upper right corner of the auditing screen Select a record with the mouse cursor then press the Delete key on the keyboard 5 Generate logs in one of the following ways In the short cut menu right click and select Generate log Click the Generate log button Besides generating a report you can also generate a log file with the same information as for the report Open and see the deta...

Page 88: ...000051 1 en vsd GUID 3F080E48 8B77 48A0 8283 89511E1AE50B V1 EN Figure 27 Zooming via the shortcut menu Use the mouse to zoom in and select a part of the graph area IEC11000052 1 en vsd GUID 261171B2 59CD 4248 B873 39A2BC3CD1F1 V1 EN Figure 28 Zooming via area selection of a part of the graph Press PgUp key on the keyboard to zoom in and PgDn to zoom out Section 7 1MRK502053 UEN B Calibrating inje...

Page 89: ... This file can then be imported to other tools for deeper analysis when needed The logger feature is available on the lower right corner of the Monitoring tab Note that the logger is independent of graph plotting 1 Select the Browse button See figure Figure 15 2 Navigate to a desired folder 3 Type a suitable file name for the txt file and select Save 4 To start logging to this file select the Star...

Page 90: ...84 ...

Page 91: ...iguration Communication Station communication Port configuration SLM optical serial port PROTOCOL 1 When the setting is entered the IED restarts automatically After the restart the SPA IEC port operates as a SPA port 2 Set the slave number and baud rate for the rear SPA port The slave number and baud rate can be found on the local HMI under Main menu Configuration Communication Station communicati...

Page 92: ... there are some different methods Choose one of the following 8 2 1 Verifying SPA communication Procedure 1 Use a SPA emulator and send RF to the IED The answer from the IED should be the type and version of it for example REL670 2 1 2 Generate one binary event by activating a function which is configured to an EVENT block where the used input is set to generate events on SPA The configuration mus...

Page 93: ...he fibre optic loop can contain 20 30 IEDs depending on requirements on response time Connection to a personal computer PC can be made directly if the PC is located in the substation or by telephone modem through a telephone network with ITU CCITT characteristics Table 4 Max distances between IEDs nodes glass 1000 m according to optical budget plastic 25 m inside cubicle according to optical budge...

Page 94: ...88 ...

Page 95: ...with here Control Center IED IED IED Gateway Star coupler RER 111 Station HSI MicroSCADA IEC05000663 1 en vsd IEC05000663 V2 EN Figure 29 Example of LON communication structure for a substation automation system An optical network can be used within the substation automation system This enables communication with the IEDs through the LON bus from the operator s workplace from the control center an...

Page 96: ...n but one very central unit needed is the LON Star Coupler and optical fibres connecting the star coupler to the IEDs To interface the IEDs from the MicroSCADA with Classic Monitor application library LIB520 is required The HV Control 670 software module is included in the LIB520 high voltage process package which is a part of the Application Software Library in MicroSCADA applications The HV Cont...

Page 97: ... reset the LON port of the IED Path in the local HMI under Main menu Configuration Communication SLM configuration Rear optical LON port These parameters can only be set with the LON Network Tool LNT Table 7 Setting parameters for the LON communication Parameter Range Default Unit Parameter description DomainID 0 0 Domain identification number SubnetID 0 255 Step 1 0 Subnet identification number N...

Page 98: ...rs the node address to the LON Network Tool 9 2 Optical budget calculation for serial communication with LON Table 11 Example Distance 1 km Glass Distance10 m Plastic Maximum attenuation 11 dB 7 dB 4 dB km multi mode 820 nm 62 5 125 um 4 dB 0 3 dB m plastic 620 nm 1mm 3 dB Margins for installation aging and so on 5 dB 2 dB Losses in connection box two contacts 0 75 dB contact 1 5 dB Losses in conn...

Page 99: ...rear ports AB and CD Navigate to Main menu Configuration Communication Ethernet configuration LANAB 1 Set values for Mode IPAddress and IPMask Mode must be set to Normal Check that the correct IP address is assigned to the port 1 2 Enable IEC 61850 8 1 communication Navigate to Main menu Configuration Communication Station communication IEC61850 8 1 IEC61850 8 1 1 Set Operation to On and PortSelGO...

Page 100: ...h port AB and CD Browse in the local HMI to Main menu Diagnostics Communication Redundant PRP and check that both signals LAN A STATUS and LAN B STATUS are shown as Ok Remove the optical connection to one of the ports AB or CD Verify that either signal LAN A STATUS or LAN B STATUS depending on which connection that was removed are shown as Error and the that other signal is shown as Ok Be sure to ...

Page 101: ...ctionality summaries function blocks logic diagrams input and output signals setting parameters and technical data sorted per function The test equipment should be able to provide a three phase supply of voltages and currents The magnitude of voltage and current as well as the phase angle between voltage and current must be variable The voltages and currents from the test equipment must be obtaine...

Page 102: ...s restarted For more information about the flash memory refer to section Configuring the IED and changing settings 11 1 2 Preparing the IED to verify settings If a test switch is included start preparation by making the necessary connections to the test switch This means connecting the test equipment according to a specific and designated IED terminal diagram Put the IED into the test mode to faci...

Page 103: ...tion s before testing Most functions are highly flexible and permit a choice of functional and tripping modes The various modes are checked at the factory as part of the design verification In certain cases only modes with a high probability of coming into operation need to be checked when commissioned to verify the configuration and settings 11 2 Activating the test mode Put the IED into the test...

Page 104: ...est switch of the other without altering the previous connections Use COMBITEST test system to prevent unwanted tripping when the handle is withdrawn since latches on the handle secure it in the half withdrawn position In this position all voltages and currents are restored and any re energizing transients are given a chance to decay before the trip circuits are restored When the latches are relea...

Page 105: ...o be tested Release or unblock the function to be tested This is done to ensure that only the function or the chain of functions to be tested are in operation and that other functions are prevented from operating Release the tested function s by setting the corresponding Blocked parameter under Function test modes to No in the local HMI When testing a function in this blocking feature remember tha...

Page 106: ...o be released 3 Set parameter Blocked for the selected function to No 11 6 Verifying analog primary and secondary measurement Verify that the connections are correct and that measuring and scaling is done correctly This is done by injecting current and voltage to the IED Apply input signals as needed according to the actual hardware and the application configuration 1 Inject a symmetrical three ph...

Page 107: ...n Verify operating levels trip and timers Verify alarm and blocking signals Use the disturbance handling tool in PCM600 to evaluate that the protection function has received the correct data and responded correctly signaling and timing Use the event viewer tool in PCM600 to check that only expected events have occurred 1MRK502053 UEN B Section 11 Testing IED operation Generator protection REG670 2...

Page 108: ...102 ...

Page 109: ...isturbance report can be made active or inactive If the disturbance recorder is turned on during test mode recordings will be made When test mode is switched off all recordings made during the test session are cleared Setting OpModeTest for the control of the disturbance recorder during test mode are located on the local HMI under Main menu Settings IED Settings Monitoring Disturbance report DRPRD...

Page 110: ... be useful to have a printer for hard copies The correct start criteria and behavior of the disturbance recording function can be checked when IED protective functions are tested When the IED is brought into normal service it is recommended to delete all recordings made during commissioning to avoid confusion in future fault analysis All recordings in the IED can be deleted in two ways 1 in the lo...

Page 111: ...nu Test Function test modes Current protection is set to Off since they are configured to the same current transformer inputs as the transformer differential protection Make sure that the transformer differential functions T2WPDIF or T3WPDIF are unblocked 2 Connect the test set for injection of three phase currents to the current terminals of the IED which are connected to the CTs on the HV side o...

Page 112: ...nic blocking can be tested in a similar way For more detailed formulas please refer to the application manual 12 3 1 2 Completing the test Continue to test another function or end the test by changing the TestMode setting to Off Restore connections and settings to their original values if they were changed for testing purposes 12 3 2 High impedance differential protection HZPDIF Prepare the IED fo...

Page 113: ...1 2 ˣ U Alarm and measure the alarm time 9 Check that trip and alarm outputs operate according to the configuration logic 10 Finally check that start and alarm information is stored in the event menu and if a serial connection to the SA is available verify that the correct and only the required signals are presented on the local HMI and on the SCADA system Information on how to use the event menu ...

Page 114: ... of about 20 assumes 15 setting on I1 I2 ratio parameter can be added to the fundamental tone in phase L1 Increase the current in phase L1 above the start value measured in step 3 Repeat test with current injection in phases L2 and L3 respectively Fifth harmonic blocking can be tested in a similar way The balancing of currents flowing into and out of the differential zone is typically checked by p...

Page 115: ...ormation is stored in the event and disturbance recorder 12 3 4 2 Completing the test Continue to test another function or end the test by changing the TestMode setting to Off Restore connections and settings to their original values if they were changed for testing purposes 12 4 Impedance protection 12 4 1 Full scheme distance protection mho characteristic ZMHPDIS Prepare the IED for verification...

Page 116: ...igure 31 and Figure 32 and Table 12 and Table 13 In cases where the load encroachment characteristic is activated tests according to the adjusted figures should be carried out To verify the settings for the operating points according to the following fault types should be tested One phase to phase fault One phase to earth fault The shape of the operating characteristic depends on the values of the...

Page 117: ...set R R1set 3 X 0 8 x X1set R 0 8 x R1set RFPP 2 4 X 0 5 x X1set R 0 5 x R1set RFPP 2 5 X 0 85 x RFPP x tan ArgLd ArgLd angle for the maximal load transfer R 0 85 x RFPP 6 X RLdFw x tan ArgLd R RLdFw 7 X 0 R RLdFw 8 X 0 2143 x RFPP 2 Exact 0 8 x RFPP 2 ArgDir 20 R 0 8 x RFPP 2 9 X 0 4 x RLdFw x tan ArgDir 20 R 0 4 x RLdFw 10 X 0 5 x X1set Exact 0 5 x R1set x tan ArgNegRes 30 R 0 23 x X1set Table c...

Page 118: ... vsd IEC05000369 V3 EN Figure 32 Distance protection characteristic with test points for phase to earth measurements Table 13 is used in conjunction with Figure 32 Table 13 Test points for phase to earth L3 E Ohm Loop Test point Reach Value Comments 1 X 2 x X1set X0set 3 R 0 2 X 2 x X1set X0set 3 R 2 x R1set R0set 3 3 X 0 8 x 2 x X1set X0set 3 R 0 8 x 2 x R1set R0set 3 RFPEset 4 X 0 5 x 2 x X1set ...

Page 119: ...hase to phase fault L1 L2 1 Subject the IED to healthy normal load conditions for at least two seconds 2 Apply the fault condition and slowly decrease the measured impedance to find the operating value of the phase to phase fault for zone 1 according to test point 1 in Figure 31 and Table 12 Compare the result of the measurement with the set value 3 Repeat steps 1 to 2 to find the operating value ...

Page 120: ...t tested have to be blocked and the zone that is tested has to be released When the load shaped characteristic is activated OperationLdCmp On the test point for phase to phase faults is 12 in Figure 31 and Table 12 and for phase earth faults according to test point 12 in Figure 32 and Table 13 12 4 2 3 Completing the test Continue to test another function or end the test by changing the TestMode s...

Page 121: ...rameters The figures illustrating the characteristic for the distance protection function can be used for settings with and without load encroachment The solid lines designate the diagram applicable when the load current compensation operationLdCom parameter is set to 1 On This is the default setting The solid line and all test points except 13 are valid for this setting When it is set to 0 Off th...

Page 122: ...rgLd R 0 8 X 0 2143 x RFPP 2 Exact 0 8 x RFPP 2 ArgDir 20 R 0 8 x RFPP 2 9 X 0 4 x RLdFw x tan ArgDir 20 R 0 4 x RLdFw 10 X 0 5 x X1set Exact 0 5 x R1set x tan ArgNegRes 30 R 0 23 x X1set 11 X 0 8 x X1set Exact 0 5 x R1set x tan ArgNegRes 30 R 0 37 x X1 set 12 X 0 5 x X1set R 0 5 x R1set 13 X 0 Only used when OperationLdCmp setting is 0 Off R 0 5 x RFPP Table 12 is used in conjunction with figure ...

Page 123: ...set X0set 3 R 0 2 X 2 x X1set X0set 3 R 2 x R1set R0set 3 3 X 0 8 x 2 x X1set X0set 3 R 0 8 x 2 x R1set R0set 3 RFPEset 4 X 0 5 x 2 x X1set R0set 3 R 0 5 x 2 x R1set R0set 3 RFPEset 5 X 0 85 x RFPEset x tan ArgLdset ArgLd angle for the maximal load transfer R 0 85 x RFPE 6 X RLdFwset x tan ArgLdSet R RLdFwset 7 X 0 R RLdFwset 8 X 02143 x RLdFwset Exact 0 8 x RFPE x tan ArgDir 20 R 0 8 x RLdFwset 9...

Page 124: ...he operating value for test point 2 3 in table 12 and the operating value for the phase to earth loop according to test point 1 2 3 in table 13 Observe that the zones that are not tested have to be blocked and the zone that is tested has to be released 4 Repeat steps 1 to 3 to find the operating value for the phase to earth fault L3 E according to figure 32 and table 13 Test points 8 and 9 are int...

Page 125: ...values if they were changed for testing purposes 12 4 4 Pole slip protection PSPPPAM Prepare the IED for verification of settings as outlined in section Requirements and section Preparing for test in this chapter 12 4 4 1 Verifying the settings It is assumed that setting of the pole slip protection function PSPPPAM is done according to impedances as seen in figure 35 and figure 36 The test is done...

Page 126: ...nce is reached after 1 second As the injected voltage is lower than 0 92 UBase the START signal should be activated In addition to this the signal ZONE1 should be activated 5 Set N1Limit to 1 and repeat step 4 Now the signals TRIP1 and TRIP should be activated 6 With reduced amplitude of the injected voltage to 0 8 UBase the current amplitude and angle is changed via ZC ZA ZC 2 to a value correspo...

Page 127: ...vement Zone 2 Zone 1 WarnAngle TripAngle f ZC IEC07000099_2_en vsd IEC07000099 V2 EN Figure 35 Setting of the pole slip protection PSPPPAM 1MRK502053 UEN B Section 12 Testing functionality by secondary injection Generator protection REG670 2 0 IEC 121 Commissioning manual ...

Page 128: ...urpose of the OOSPPAM function is to detect evaluate and take the required action during pole slipping occurrences in the power system The OOSPPAM function detects pole slip conditions and trips the generator as fast as possible after the first pole slip if the center of oscillation is found to be in zone 1 which normally includes the generator and its step up power transformer If the center of os...

Page 129: ...s to be detected and confirmed The test may be performed by taking into account the following key points that are shown in Figure 37 the point RE RE Receiving End the intersection between the line segment SE RE and the X line which is defined through the setting ReachZ1 the point SE SE Sending End I I 50 Hz I 49 5 Hz IEC10000141 V2 EN Figure 37 Trajectory of the impedance Z R X for the injected cu...

Page 130: ...tance is X ReachZ ForwardX ZBase RZ1 1 100 100 12 100 59 33 100 0 9522 0 0 068Ω EQUATION14044 V1 EN Equation 4 The calculation of the test voltage that is related to ReachZ1 is based on the impedance ZRZ1 that has imaginary part XRZ1 and real part RRZ1 RRZ achZ ForwardR ZBase 1 1 100 100 12 100 8 19 100 0 9522 0 0 Re 0 09Ω EQUATION14045 V1 EN Equation 5 The magnitude of the impedance ZRZ1 is 2 2 2...

Page 131: ...spectively 9000 1 A and 13 8 0 1 kV in the example The magnitude of the secondary voltages that are related to the points RE and SE of the R X plane needs to be checked RE RFwdR XFwdX V V V V V t FwdZs t FwdZ VT s VT p 11931 0 1 13 8 86 45 EQUATION14054 V1 EN Equation 14 SE RRvsR XRvsX V V V V V t RvsZs t RvsZ VT s VT p 5899 0 1 13 8 42 75 EQUATION14055 V1 EN Equation 15 The tests which are descri...

Page 132: ...se current where the current is the summation of two currents that have the same magnitude but different frequencies I I A tf t I 50 2 20918 2 10459 GUID F02E8D18 FF87 45BE 8142 E8FA19F6966B V1 EN Equation 16 The first current I50 has frequency 50 Hz magnitude 10459 A that is 1 162 A secondary and phase angle 0º The second current Itf has magnitude 10459 A that is 1 162 A secondary phase angle 180...

Page 133: ...ate IED terminals 3 Connect in parallel two groups of three phase currents of the test set to the appropriate IED terminals 4 Connect the appropriate trip output of the IED to the input channel of the test set that monitors the trip 5 Go to Main menu Settings IED Settings Impedance protection OutOfStep 78 Ucos OOSPPAM 78 Ucos 1 and make sure that the function is enabled that is Operation is set to...

Page 134: ...r TRIP is issued Execution of the dynamic test The test may be performed by using two states of a sequence tool that is a basic feature of test sets State 1 pre test condition Steady voltage and current are applied in order to get a steady high impedance ThisisapointintheplaneR Xthatisfarawayfromthelenscharacteristic Define the following three phase symmetrical quantities the phase angle is relate...

Page 135: ...ion does not issue either start or trip The trajectory of the impedance traverses the lens characteristic in zone 2 Preliminary steady state test at 50 Hz Go to Main menu Test Function status Impedance protection OutOfStep 78 Ucos OOSPPAM 78 Ucos 1 Outputs to check the available service values of the function block OOSPPAM Apply the following three phase symmetrical quantities the phase angle is r...

Page 136: ...o TRIP is performed Execution of the dynamic test The test may be performed by using two states of a sequence tool that is a basic feature of test sets State 1 pre test condition Steady voltage and current are applied in order to get a steady high impedance that is a point in the plane R X which is far away from the lens characteristic Define the following three phase symmetrical quantities the ph...

Page 137: ...ns are fulfilled 12 4 5 3 Test of the boundary between zone 1 and zone 2 which is defined by the parameter ReachZ1 The trajectory of the impedance traverses the lens characteristic in zone 2 Preliminary steady state test at 50 Hz Go to Main menu Test Function status Impedance protection OutOfStep 78 Ucos OOSPPAM 78 Ucos 1 Outputs to check the available service values of the function block OOSPPAM ...

Page 138: ...ne 1 and zone 2 The START is issued but no TRIP is performed Execution of the dynamic test The test may be performed by using two states of a sequence tool that is a basic feature of test sets State 1 pre test condition Steady voltage and current are applied in order to get a steady high impedance that is a point in the plane R X that is far away from the lens characteristic Define the following t...

Page 139: ... of the protection function and trip in zone 2 when trip conditions are fulfilled The trajectory of the impedance traverses the lens characteristic in zone 1 Preliminary steady state test at 50 Hz Go to Main menu Test Function status Impedance protection OutOfStep 78 Ucos OOSPPAM 78 Ucos 1 Outputs to check the available service values of the function block OOSPPAM Apply the following three phase s...

Page 140: ...1 and zone 2 The START is issued but no TRIP is performed Execution of the dynamic test The test may be performed by using two states of a sequence tool that is a basic feature of test sets State 1 pre test condition Steady voltage and current are applied in order to get a steady high impedance that is a point in the plane R X which is far away from the lens characteristic Define the following thr...

Page 141: ...Expected result start of the protection function and trip in zone 1 when trip conditions are fulfilled 12 4 5 4 Test of the point SE RRvsR XRvsX The trajectory of the impedance traverses the lens characteristic in zone 1 Preliminary steady state test at 50 Hz Go to Main menu Test Function status Impedance protection OutOfStep 78 Ucos OOSPPAM 78 Ucos 1 Outputs to check the available service values ...

Page 142: ...ens characteristic in zone 1 that is close to the point SE The START is issued but no TRIP is performed Execution of the dynamic test The test may be performed by using two states of a sequence tool that is a basic feature of test sets State 1 pre test condition Steady voltage and current are applied in order to get a steady high impedance that is a point in the plane R X which is far away from th...

Page 143: ... V1 EN Equation 66 Itfs 180º frequency of Itfs 50 5 Hz Expected result start of the protection function and trip in zone 1 when trip conditions are fulfilled The trajectory of the impedance does not enter the lens characteristic Preliminary steady state test at 50 Hz Go to Main menu Test Function status Impedance protection OutOfStep 78 Ucos OOSPPAM 78 Ucos 1 Outputs to check the available service...

Page 144: ...e the lens characteristic even if it is close to the point SE Neither START nor TRIP is issued Execution of the dynamic test The test may be performed by using two states of a sequence tool that is a basic feature of test sets State 1 pre test condition Steady voltage and current are applied in order to get a steady high impedance that is a point in the plane R X which is far away from the lens ch...

Page 145: ... Equation 74 frequency of Vts 50 Hz I I I I A s CTs CTp 50 50 10459 1 9000 1 162 EQUATION14059 V1 EN Equation 75 I50s 0º frequency of I50s 50 Hz It I I I A fs CTs CTp tf 10459 1 9000 1 162 EQUATION14062 V1 EN Equation 76 Itfs 180º frequency of Itfs 50 5 Hz Expected result the protection function does not issue either start or trip After each test it is possible to download and study the related di...

Page 146: ...s The test is done by means of injection of three phase current and three phase voltage from a modern test device This test device shall be able to give voltage and current corresponding to the set apparent impedance 1 Feed the IED with current and voltage corresponding to the apparent impedance Test 1 as shown in figure 39 Read the analog outputs for R and X and check that this reading correspond...

Page 147: ...tage corresponding to the apparent impedance Test 4 as shown in figure 39 Read the analog outputs for R and X and check that this reading corresponds to the injected impedance The signals START STZ2 and STZ1 shall be activated instantaneously and the signals TRIP TRZ2 and TRZ1 shall be activated after the different set time delays 6 Switch the current infeed injection off The function shall reset ...

Page 148: ...shows the same signals that are available on the local HMI 12 4 7 1 Verifying the settings Distance protection zones While measuring operating characteristics keep the current constant Keep the current as close as possible to its rated value or lower however make sure it is higher than 30 of the rated current If the measurement of the operating characteristics runs under constant voltage condition...

Page 149: ...Angle P3 Z1Fwd Z1Rev 2 sin LineAngle Z1Fwd 2 1 cos LineAngle Z1Rev 2 1 cos LineAngle P4 Z1Rev sinLineAngle Z1Rev cos LineAngle Change the magnitude and angle of phase to phase voltage to achieve impedances at test points P1 P2 P3 and P4 For each test point observe that the output signals START and STZ1 are activated where x refers to the actual phase to be tested After the operate time delay for t...

Page 150: ... 2 sin LineAngle ZxFwd 2 1 cos LineAngle ZxRev 2 1 cos LineAngle P3 ZxFwd ZxRev 2 sin LineAngle ZxFwd 2 1 cos LineAngle ZxRev 2 1 cos LineAngle P4 ZxRev sin LineAngle ZxRev cos LineAngle Change the magnitude and angle of phase to phase voltage to achieve impedances at test points P1 P2 P3 and P4 For each test point observe that the output signals START and STZx are activated where x is 2 or 3 depe...

Page 151: ...and phase to phase loops Under voltage seal in The under voltage seal in logic can be verified using the TRUV and STUV outputs Steps to verify the logic 1 Keep all the current and voltage in normal balanced condition 2 Keeping the phase current at rated value slowly reduce the voltage till it enters into the respective zone mho characteristics and also below the set value of the under voltage seal...

Page 152: ...transformer with a primary winding for connection to 120 or 230 V 50 or 60 Hz supply voltage From the secondary winding of this internal voltage transformer approximately 40 V AC is injected via series capacitors and resistors into the rotor circuit The injected voltage is fed to a voltage input of the REG670 IED The current caused by the injection is fed to a current input of the REG670 IED via a...

Page 153: ... generator at stand still situations Procedure 1 The test should be prepared with a switch connected between the output of RXTTE4 221 and the station earth Initially this switch is open 2 First the 120 230 V input to RXTTE4 is disconnected This should give a signal from REG670 that the injection voltage is low 3 Reconnect the 120 230 V input and check that the low injection voltage signal resets 1...

Page 154: ...original values if they were changed for testing purposes 12 5 Current protection 12 5 1 Instantaneous phase overcurrent protection 3 phase output PHPIOC Prepare the IED for verification of settings outlined in section Requirements and section Preparing for test in this chapter To verify the settings the following fault type should be tested Phase to earth fault Ensure that the maximum continuous ...

Page 155: ...rrents for operation is chosen Connect the injection current to phases L1 and neutral If 2 out of 3 currents for operation is chosen Connect the injection current into phase L1 and out from phase L2 If 3 out of 3 currents for operation is chosen Connect the symmetrical three phase injection current into phases L1 L2 and L3 2 Connect the test set for the appropriate three phase voltage injection to...

Page 156: ...operate current for txMin 11 Check that all trip and start contacts operate according to the configuration signal matrixes 12 Reverse the direction of the injected current and check that the protection does not operate 13 If 2 out of 3 or 3 out of 3 currents for operation is chosen Check that the function will not operate with current in one phase only 14 Repeat the above described tests for the h...

Page 157: ...n Preparing for test in this chapter 12 5 4 1 Four step directional earth fault protection 1 Connect the test set for single current injection to the appropriate IED terminals Connect the injection current to terminals L1 and neutral 2 Set the injected polarizing voltage slightly larger than the set minimum polarizing voltage default 5 of Ur and set the injection current to lag the voltage by an a...

Page 158: ... polarizing voltage 12 5 4 3 Completing the test Continue to test another function or end the test by changing the TestMode setting to Off Restore connections and settings to their original values if they were changed for testing purposes 12 5 5 Four step negative sequence overcurrent protection NS4PTOC Prepare the IED for verification of settings as outlined in section Preparing for test in this ...

Page 159: ...t steps according to the instructions that follow 7 Connect a trip output contact to a timer 8 Set the injected current to 200 of the operate level of the tested step switch on the current and check the time delay For inverse time curves check the operate time at a current equal to 110 of the operate current in order to test parameter txmin 9 Check that all trip and start contacts operate accordin...

Page 160: ...e the current lagging the voltage Take setting RCAComp into consideration if not equal to 0 2 Inject current until the function picks up and make sure that the operate current of the set directional element is equal to the INcosPhi setting The I Dir 3I0 cosφ function activates the START and STDIRIN output 3 Assume that φ is the phase angle between injected voltage 3U0 and current 3I0 i e φ RCADir ...

Page 161: ...d increase until the boolean output signal UNREL is activated which is visible in the Application Configuration in PCM600 when the IED is in online mode Compare the voltage with the set value UNRel 8 Continue to test another function or complete the test by setting the test mode to Off Operate area ROADir IEC06000650_2_en vsd o 0 RCADir 0 3I j 0 3 j I cos 0 3 ref U U IEC06000650 V2 EN Figure 44 Ch...

Page 162: ...the set directional element Note that for operation both the injected current and voltage must be greater than the set values INRel and UNRel respectively The function activates the START and STDIRIN outputs 3 Assume that φ is the phase angle between injected voltage 3U0 and current 3I0 i e φ RCADir φ Change φ to for example 45 degrees Increase the injected current until the function operates 4 Co...

Page 163: ... to the INDir setting for the set directional element Note that for operation both the injected current and voltage must be greater than the set values INRel and UNRel respectively The function activates the START and STDIRIN output 3 Measure with angles j around RCADir ROADir 4 Compare the result with the set values refer to figure 46 for example characteristic 5 Measure the operate time of the t...

Page 164: ...nother function or complete the test by setting the test mode to Off Residual overvoltage release and protection Procedure 1 Measure that the operate voltage is equal to the UN setting The function activates the START and STUN signals 2 Measure the operate time by injecting a voltage 1 2 times set UN operate value 3 Compare the result with the set tUN operate value 4 Inject a voltage 0 8 UNRel and...

Page 165: ...se1 for phases L2 and L3 5 Activate the cooling input signal thus switching to base current IBase2 6 Check the operate and reset values for all three phases for IBase2 in the same way as described above for stage IBase1 7 Deactivate the input signal for stage IBase2 8 Set the time constant for IBase1 in accordance with the setting plan 9 Set the injection current for phase L1 to 1 50 IBase1 10 Con...

Page 166: ...ion Preparing for test in this chapter The Breaker failure protection 3 phase activation and output function CCRBRF should normally be tested in conjunction with some other function that provides a start signal An external START signal can also be used To verify the settings in the most common back up trip mode 1 out of 3 it is sufficient to test phase to earth faults At mode 2 out of 4 the phase ...

Page 167: ...lt condition including start of CCRBRF well above the set current value Measure time from START of CCRBRF 2 Check the re trip t1 and back up trip times t2 and t3 Inapplicable cases theback uptripformulti phasestartt2MPhandback uptrip 2 t2 and t3 can also be checked To check t2MPh a two phase or three phase start shall be applied 3 Disconnect AC and START input signals 12 5 8 4 Verifying the re tri...

Page 168: ...ping Use the actual tripping modes The case below applies to re trip with current check 1 Apply the fault condition including start of CCRBRF with phase current well above set value IP 2 Interrupt the current with a margin before back up trip time t2 It may be made at issue of re trip command 3 Check that re trip is achieved if selected but no back up trip is obtained The normal mode BuTripMode 1 ...

Page 169: ...d to input CBFLT 1 Repeat the check of back up trip time Disconnect current and START input signals 2 Activate the input CBFLT The output CBALARM CB faulty alarm should appear after set time tCBAlarm Keep the input activated 3 Apply the fault condition including start of CCRBRF with current above set current value 4 Verify that back up trip is obtained without intentional delay for example within ...

Page 170: ... 3 3 Apply the fault condition with input signal s for start of CCRBRF The value of current should be below the set value I BlkCont 4 Verify that phase selection re trip if selected and back up trip are achieved after set times Failure to trip is simulated by keeping the signal s CB closed activated 5 Disconnect the input signal and the START signal s Keep the CB closed signal s 6 Apply the fault ...

Page 171: ...sure the operating time of the CCPDSC protection Use the TRIP signal from the configured binary output to stop the timer 12 Deactivate the CLOSECMD Set measured current in one phase to 90 of Current Release level Activate CLOSECMD NO TRIP signal should appear 13 Repeat the previous two steps using OPENCMD instead of CLOSECMD Asymmetry current detection with CB monitoring Set all three currents to ...

Page 172: ... application If a three phase test set is available this could be used for all the modes If a single phase current voltage test set is available the test set should be connected to a selected input for one phase current and voltage Table 16 Calculation modes Set value Mode Formula used for complex power calculation L1 L2 L3 1 1 2 2 3 3 L L L L L L S U I U I U I EQUATION1697 V1 EN Equation 80 Arone...

Page 173: ...until the START1 signal start of stage 1 is activated 5 Increase the current to 100 of IBase 6 Switch the current off and measure the time for activation of TRIP1 trip of stage 1 7 If a second stage is used repeat steps 2 to 6 for the second stage 12 5 10 2 Completing the test Continue to test another function or end the test by changing the TestMode setting to Off Restore connections and settings...

Page 174: ...e START1 signal start of stage 1 is activated Check the injected power and compare it to the set value Power1 power setting for stage 1 in of Sbase 5 Increase the current to 100 of IBase and switch the current off 6 Switch the current on and measure the time for activation of TRIP1 trip of stage 1 7 If a second stage is used repeat steps 2 to 6 for the second stage 12 5 11 2 Completing the test Co...

Page 175: ...ates Start signal ST1 must be activated when amplitude of the negative sequence current lies slightly above the start level I2 1 Corresponding trip signals TR1 and TRIP is activated after the pre set time delay has expired Note Block or disable operation of step 2 when testing step 1 if the injected current activates the step 2 6 Decrease the current slowly and note the reset value 7 Connect a tri...

Page 176: ... for testing purposes Make sure that all built in features for this function which shall be in operation are enabled and with correct settings 12 5 13 Accidental energizing protection for synchronous generator AEGPVOC Prepare the IED for verification of settings outlined in section Requirements and section Preparing for test in this chapter 12 5 13 1 Verifying the settings 1 Connect the test set f...

Page 177: ...otection VoltageRestOverCurr 51V 2 I U VRPVOC 51V 2 I U 1 General and make sure that the function is enabled that is Operation is set to On 3 The test of the function may be performed by injecting restrain voltage and increasingtheinjectedcurrent s NotethevalueatwhichtheSTART andSTOC signals are set In the following equations restrain voltage is the magnitude of the minimum phase to phase voltage ...

Page 178: ... between 0 25 UBase and UHighLimit 100 UBase UL1 Ampl 50 3 Angle 0 UL2 Ampl 50 3 Angle 240 UL3 Ampl 100 3 Angle 120 Last section of the characteristic If VDepMode either Slope or Step the minimum measured phase to phase voltage is higher than UHighLimit 100 UBase UL1 Ampl 105 3 Angle 0 UL2 Ampl 105 3 Angle 240 UL3 Ampl 105 3 Angle 120 4 Inject the voltages that are related to the first part of the...

Page 179: ...ured value for example phase current StartCurr Set operate value This means that if the measured phase current jumps from 0 to 2 times the set operate level and time multiplier k is set to 1 0 s default value then the TROC and TRIP signals will operate after a time delay equal to 13 5 s tolerance Taking into account the above explanation inject the voltages related to the last part of the characte...

Page 180: ...s well as the trip signals of the function block TRIP and TRUV 18 Instantaneously decrease the voltage in two phases simultaneously to a value 20 lower than the set operate value take into account the previous note if VRPVOC is configured in ACT with the undervoltage seal in feature 19 Measure the definite time delay for the TRUV and TRIP signals and compare it with the set value tDef_UV 20 Check ...

Page 181: ... menu 12 5 15 2 Completing the test Continue to test another function or end the test by changing the Test mode setting to Off Restore connections and settings to their original values if they were changed for testing purposes Make sure that all built in features for this function which shall be in operation are enabled and with correct settings 12 5 16 Generator rotor overload protection GRPTTR 1...

Page 182: ...12 Set the injected current to 100 of IBase and switch on the current 13 Decrease the current slowly under I 14 The signal TRIPUC will be activated when timer tTrip_I expires 15 Finally check that start and trip information is stored in the event menu Testing the protection 12 5 16 2 Completing the test Continue to test another function or end the test by changing the Test mode setting to Off Rest...

Page 183: ... Increase the measured voltage to rated load conditions 6 Check that the START signal resets 7 Instantaneously decrease the voltage in one phase to a value about 20 lower than the measured operate value 8 Measure the time delay for the TRIP signal and compare it with the set value 9 Check the inverse time delay by injecting a voltage corresponding to 0 8 U1 For example if the inverse time curve A ...

Page 184: ...PTOV Prepare the IED for verification of settings outlined in section Requirements and section Preparing for test in this chapter 12 6 2 1 Verifying the settings Verification of single phase voltage and time delay to operate for Step 1 1 Apply single phase voltage below the set value U1 2 Slowly increase the voltage until the ST1 signal appears 3 Note the operate value and compare it with the set ...

Page 185: ...n Requirements and section Preparing for test in this chapter 12 6 3 1 Verifying the settings 1 Apply the single phase voltage either to a single phase voltage input or to a residual voltage input with the start value below the set value U1 2 Slowly increase the value until ST1 appears 3 Note the operate value and compare it with the set value 4 Decrease the voltage slowly and note the reset value...

Page 186: ...tion protection OEXPVPH is configured for a three phase voltage input A single phase injection voltage is applied if the function is configured for a phase to phase voltage input OEXPVPH is conveniently tested using rated frequency for the injection voltage and increasing the injection voltage to get the desired overexcitation level 3 Connect the alarm contact to the timer and set the time delay t...

Page 187: ...nging the TestMode setting to Off Restore connections and settings to their original values if they were changed for testing purposes 12 6 5 Voltage differential protection VDCPTOV Prepare the IED for verification of settings as outlined in section Requirements and section Preparing for test in this chapter 12 6 5 1 Check of undervoltage levels This test is relevant if the setting BlkDiffAtULow Ye...

Page 188: ...he START signal resets 4 Check U1 blocking level by comparing the voltage level at reset with the set undervoltage blocking U1Low 5 Repeat steps 2 to 4 to check U1Low for the other phases The connections to U1 must be shifted to test another phase UL1 to UL2 UL2 to UL3 UL3 to UL1 Check of U2Low Procedure 1 Connect voltages to the IED according to valid connection diagram and figure 48 Section 12 1...

Page 189: ...hase of the U2 inputs according to figure 48 The voltage differential START signal is set 3 Decrease slowly the voltage in phase UL3 of the test set until the START signal resets 4 Check U2 blocking level by comparing the voltage level at reset with the set undervoltage blocking U2Low 12 6 5 2 Check of voltage differential trip and alarm levels Procedure 1 Connect voltages to the IED according to ...

Page 190: ...arm 4 Check the alarm operation level by comparing the differential voltage level at ALARM with the set alarm level UDAlarm 5 Continue to slowly decrease the voltage until START signal is activated 6 Check the differential voltage operation level by comparing the differential voltage level at START with the set trip level UDTrip 7 Repeat steps 1 to 6 to check the other phases Observe that the conn...

Page 191: ...PTOV 60 VDCPTOV x The IED voltage inputs should be connected to the VTs according to valid connection diagram 2 Record the differential voltages 3 Calculate the compensation factor RFLx for each phase For information about calculation of the compensation factor see the application manual 4 Set the compensation factors on the local HMI under Main menu Settings Settings group N Voltage protection Vo...

Page 192: ...voltages 180 Check the monitored values of the following analogue signals E3 the magnitude of the third harmonic induced voltage in the stator U3N 5 V the magnitude of the third harmonic voltage measured at the neutral side of the generator U3T 15 V the magnitude of the third harmonic voltage measured at the terminal side of the generator and ANGLE 180 the angle between the third harmonic voltage ...

Page 193: ...rator and ANGLE the angle between the third harmonic voltage phasors U3N and U3T The value of E3 should be close to the following value 2 2 3N 3T 3T E3 U U cos ANGLE U sin ANGLE EQUATION2076 V1 EN Equation 103 Make sure that ANGLE has a value bigger than 125 2 Read the value of DU differential voltage The value of DU should be close to the following value 2 2 3N 3T 3T DU U U cos ANGLE U sin ANGLE ...

Page 194: ...l the START signal appears 4 Note the operate value and compare it with the set value 5 Increase the frequency until rated operating levels are reached 6 Check that the START signal resets 7 Instantaneously decrease the frequency of the applied voltage to a value about 1 lower than the operate value a step change more than 2 will increase the time delay 8 Measure the time delay of the TRIP signal ...

Page 195: ...ng for test in this chapter 12 7 2 1 Verifying the settings Verification of START value and time delay to operate 1 Check that the settings in the IED are appropriate for example the START value and the time delay 2 Supply the IED with three phase voltages at their rated values 3 Slowly increase the frequency of the applied voltage until the START signal appears 4 Note the operate value and compar...

Page 196: ...tion of settings outlined in section Requirements and section Preparing for test in this chapter 12 7 3 1 Verifying the settings Verification of START value and time delay to operate 1 Check that the settings in the IED are appropriate especially the START value and the definite time delay Set StartFreqGrad to a rather small negative value 2 Supply the IED with three phase voltages at their rated ...

Page 197: ...erminals of the IED 2 Ensure that the settings in the IED are appropriate especially the CurrStartLevel FreqHighLimit FreqLowLimit UHighLimit and ULowLimit setting 3 Supply the IED with three phase currents and voltages at their rated value 4 Slowly decrease the frequency of the applied voltage until it crosses the frequency high limit and the START signal appears 5 Check that the FREQOK signal ap...

Page 198: ...ncy of the applied voltage is within the set frequency band when time approaches the tAccLimit setting value Verification of generator start and stop logic 1 Ensure that the settings in the IED are appropriate to the default settings especially the CurrStartLevel FreqHighLimit FreqLowLimit UHighLimit and ULowLimit 2 Ensure that the setting CBCheck is enabled 3 Supply the IED with three phase curre...

Page 199: ...irements and section Preparing for test in this chapter One of the new facilities within the general current and voltage protection function CVGAPC is that the value which is processed and used for evaluation in the function can be chosen in many different ways by the setting parameters CurrentInput and VoltageInput These setting parameters decide what kind of preprocessing the connected three pha...

Page 200: ...nd check the time delay For inverse time curves check the operate time at a current equal to 110 of the operate current at tMin 8 Check that TRIP and START contacts operate according to the configuration logic 9 Release the blocking of the high set stage and check the operate and reset value and the time delay for the high set stage in the same way as for the low set stage 10 Finally check that ST...

Page 201: ... voltage according to the I cos F law setting parameter DirPrinc_OC1 or DirPrinc_OC2 set to I cos F This has to be known if a more detailed measurement of the directional characteristic is made than the one described below Procedure 1 Connect the test set for injection of three phase currents and three phase voltages to the appropriate current and voltage terminals of the IED 2 Inject current s an...

Page 202: ...n Preparing for test in this chapter The Current circuit supervision function CCSSPVC is conveniently tested with the same three phase test set as used when testing the measuring functions in the IED The condition for this procedure is that the setting of IMinOp is lower than the setting of Ip Block 12 9 1 1 Verifying the settings 1 Check the input circuits and the operate value of the IMinOp curr...

Page 203: ... signals BLKZ and 3PH should not appear on the IED Only the distance protection function can operate Undervoltage dependent functions must not operate 3 Disconnect the dc voltage from the DISCPOS binary input terminal 4 Connect the nominal dc voltage to the MCBOP binary input The BLKUand BLKZ signals should appear without any time delay All undervoltage dependent functions must be blocked 5 Discon...

Page 204: ... U L L2 L3 a a EQUATION707 V2 EN Equation 105 Where UL1 UL2 and UL3 IEC00000275 V1 EN the measured phase voltages 2 3 3 1 0 5 2 j a e j p IECEQUATION00022 V2 EN 4 Compare the result with the set value consider that the set value 3U2 is in percentage of the base voltage UBase of the negative sequence operating voltage 5 Repeat steps 1 and 2 Then slowly increase the measured current in one phase unt...

Page 205: ... U0 UL1 UL2 UL3 IEC00000276 V1 EN Equation 111 Where UL1 UL2 and UL3 IEC00000275 V1 EN are the measured phase voltages 4 Compare the result with the set value of the zero sequence operating voltage consider that the set value 3U0 is in percentage of the base voltage 5 Repeat steps 1 and 2 Then slowly increase the measured current in one phase until the BLKU signal disappears 6 Record the measured ...

Page 206: ...ted values 2 Change the voltages and currents in all three phases simultaneously The voltage change must be greater than the set value for DU and the current change must be less than the set value for DI The BLKU and BLKZ signals appear without any time delay The BLKZ signal will be activated only if the internal deadline detection is not activated at the same time 3PH should appear after 5 second...

Page 207: ...usly activated Only the output circuit related to the open phase will be active i e either MAINFUF or PILOTFUF 3 Establish a normal voltage operating condition and observe the corresponding output signals MAINFUF or PILOTFUF should change to 0 in about 27 ms 4 Set normal conditions as mentioned in step 1 5 Enable the BLOCK binary input and repeat step 2 MAINFUF or PILOTFUF should not appear Checki...

Page 208: ... section Preparing for test in this chapter At commissioning and periodical checks the functions shall be tested with the used settings To test a specific function it might be necessary to change some setting parameters for example AutoEnerg Off DLLB DBLL Both ManEnerg Off Operation Off On Activation of the voltage selection function if applicable The tests explained in the test procedures below d...

Page 209: ...ection for a 1 breaker diameter with one phase voltage connected to the line side Test equipment UMeasure Ph N Ph Ph IEC05000480 4 en vsd U Bus U Line N IED U3PBB1 N UL1 UL2 UL3 N Input Phase L1 L2 L3 L12 L23 L31 UMeasure Ph N Ph Ph Input Phase L1 L2 L3 L12 L23 L31 U3PLN1 IEC05000480 V4 EN Figure 51 General test connection with three phase voltage connected to the line side 1MRK502053 UEN B Sectio...

Page 210: ...1 UL2 or UL3 line 1 voltage inputs on the IED UP3BB1 Bus1 voltage input on the IED Testing the frequency difference The frequency difference test should verify that operation is achieved when the frequency difference between bus and line is less than set value of FreqDiffMaxand above set value of FreqDiffMin The test procedure below will depend on the settings used Input STARTSYN must be activated...

Page 211: ...he voltage difference Set the voltage difference to 0 15 p u on the local HMI and the test should check that operation is achieved when the voltage difference UDiffSC is lower than 0 15 p u The settings used in the test shall be final settings The test shall be adapted to site setting values instead of values in the example below Test with no voltage difference between the inputs Test with a volta...

Page 212: ... are activated for a phase difference lower than the set value It should not operate for other values See figure 53 dj dj U Bus U Line operation U Bus No operation en05000551 vsd IEC05000551 V1 EN Figure 53 Test of phase difference 3 Change the phase angle between dφ and dφ and verify that the two outputs are activated for phase differences between these values but not for phase differences outsid...

Page 213: ... to U Line2 without changing the setting on the local HMI Check that the two outputs are not activated 12 10 1 3 Testing the energizing check During the test of the energizing check function for a single bay arrangement these voltage inputs are used U Line UL1 UL2 or UL3 line1 voltage inputs on the IED U Bus Bus voltage input on the IED General When testing the energizing check function for the ap...

Page 214: ... The test can be repeated with different values on the U Bus and the U Line Testing both directions DLLB or DBLL 1 Verify the local HMI settings AutoEnerg or ManEnerg to be Both 2 Apply a single phase voltage of 30 GblBaseSelLine to the U Line and a single phase voltage of 100 GblBaseSelBus to the U Bus 3 Check that the AUTOENOK and MANENOK outputs are activated after set tAutoEnerg respectively t...

Page 215: ...f breaker arrangement Apply a single phase voltage of 100 GblBaseSelLine to the U Line and a single phase voltage of 100 GblBaseSelBus to the U Bus Verify that correct output signals are generated 1 Connect the analog signals to the voltage inputs in pair of two for U1 and U2 Inputs U3PBB1 U3PBB2 U3PLN1 U3PLN2 2 Activate the binary signals according to the used alternative Verify the measuring vol...

Page 216: ...s on WA1_QA1 1 bus CB WA1 LINE1 LINE1_Q B9 B1SEL LN1SEL WA1 LINE2 TIE_QA1 LINE2_Q B9 B1SEL LN2SEL WA1 WA2 TIE_QA1 WA2_QA 1 B1SEL B2SEL SESRSYN 2 Operates on TIE_QA1 Tie CB LINE1 LINE2 LINE1_Q B9 LINE2_Q B9 LN1SEL LN2SEL WA1 LINE2 WA1_QA 1 LINE2_Q B9 B1SEL LN2SEL WA2 LINE1 WA2_QA 1 LINE1_Q B9 B2SEL LN1SEL WA1 WA2 WA1_QA 1 WA2_QA 1 B1SEL B2SEL SESRSYN 3 Operates on WA2_QA1 1 bus alt CB mirrored WA2 ...

Page 217: ... which are connected in a delivery specific way between bays and to the station level For that reason test the total function in a system that is either in a complete delivery system as an acceptance test FAT SAT or as parts of that system If a block unblock command is sent from remote to function while the IED is shut down this command will not be recognized after the start up thus the command th...

Page 218: ...s of the IED 2 Checking that the corresponding commands Lower or Raise are issued by the voltage control function Setting confirmation is an important step for voltage control in the installation and commissioning phase to ensure consistency of power systems base quantities alarm blocking conditions and parallel control settings for each transformer control function Before starting any test verify...

Page 219: ...e behavior of the voltage control functions for different tests may be governed by a parameter group available on the local HMI under Main menu Settings General settings Control TransformerVoltageControl ATCC 90 TR1ATCC x TR8ATCC x These parameter settings can cause a Total Block Automatic Block or Alarm for a variety of system conditions including over and under voltage over current and tap chang...

Page 220: ...me or inverse time defined by setting t1 and t1Use The command timer will operate while the measured voltage stays outside the inner deadband defined by setting UDeadbandInner If UL remains outside of the voltage range defined by UDeadband and the command timer expires the voltage control will execute a raise or lower command to the transformer tap changer This command sequence will be repeated un...

Page 221: ...ltage control function on the local HMI under Main menu Settings Setting Group N Control TransformerVoltageControl ATCC 90 TR1ATCC x TR8ATCC x Time t1 and t2l 3 Lower the voltage 1 below U1 and wait for the issue of a Raise command from the voltage control after the expiry of a constant or inverse time delay set by t1 Detection of this command will involve locating the allocated binary output for ...

Page 222: ... regulation function is not blocked and a raise command should be issued from the IED 4 Increase the applied voltage slightly above the Umax value and check for the corresponding blocking or alarm condition on the local HMI For an alarm condition the voltage regulation function is not blocked and a lower command should be issued from the IED 12 10 3 6 Check the overcurrent block function 1 Confirm...

Page 223: ...b re rline il re xline il im EQUATION2082 V1 EN Equation 116 ul im ub im xline il re rline il im EQUATION2084 V1 EN Equation 117 where ub is the complex value of the busbar voltage il is the complex value of the line current secondary side rline is the value of the line resistance xline is the value of the line reactance For comparison with the set point value the modulus of UL are according to eq...

Page 224: ... TnRXOP in the local HMI under Main menu Settings Setting group N Control TransformerVoltageControl ATCC 90 TR8ATCC x ParCtrl The general parallel arrangement of transformers are defined by setting TnRXOP to On or Off The following rules are applicable on the settings T1RXOP T4RXOP If IED T1 and T2 are connected T1RXOP shall be set to On in instance 2 of TR8ATCC T2RXOP shall be set to On in instan...

Page 225: ...ation of circulating current voltage regulation assumes two transformers in the parallel group Setting confirmation through secondary injection requires calculation of circulating currents for each transformer based on impedance values and respective compensating factors and is therefore more complex for greater than two transformers 1 Confirm that OperationPAR is set to CC for the transformers in...

Page 226: ... and LV to HV side for Transformer 2 7 Confirm that a circulating current is measured on the local HMI that is equal in magnitude to 5 of I2Base with polarity as discussed in step 6 8 Confirm the settings for Ci Compensation Factor and Xi Transformer Short Circuit Impedance Using these setting values and the measured quantity of circulating current from the local HMI Icc_i calculate the value for ...

Page 227: ...rmer can be observed as service values on the local HMI and raise lower commands detected from the binary output mapped in the Signal Matrix The voltage injection equal to USet is required for both transformers during this test 12 Confirm that a tap change command is issued from the voltage control function to compensate for the circulating current 13 Injected currents can be reversed such that th...

Page 228: ...r tap changer parallel control function TR8ATCC for all transformers connected in the parallel group which can be confirmed through interrogation of the local HMI 5 Confirm that the automatic voltage control for tap changer parallel control function TR8ATCC responds in accordance with the setting for CircCurrBk 12 10 3 9 Completing the test Continue to test another function or end the test by chan...

Page 229: ...he IED or when a separate external unit is used for reclosing purposes The instances of SMPPTRC are identical except for the name of the function block SMPPTRC The testing is preferably done in conjunction with the protection system and autoreclosing function 12 11 1 1 Three phase operating mode 1 Check that AutoLock and TripLockout are both set to Off 2 Initiate a three phase fault An adequate ti...

Page 230: ...m time of the used SMBRREC A single phase fault shall be given at the first fault A three phase trip must be initiated for the second fault Check that the corresponding trip signals appear after both faults Functional outputs TRIP TRLn and TR1P should be active during first fault No other outputs should be active Functional outputs TRIP all TRLn and TR3P should be active during second fault 5 Init...

Page 231: ...rst fault A three phase trip must be initiated for the second fault Check that the corresponding trip signals appear after both faults Functional outputs TRIP TRLn and TR1P should be active during first fault No other outputs should be active Functional outputs TRIP all TRLn and TR3P should be active during second fault 6 Initiate a single phase to earth fault and switch it off immediately when th...

Page 232: ...functional outputs TRIP and TR3P must be active and stay active after each fault CLLKOUT should be set 10 Reset the lockout All functional outputs should reset 11 Deactivate the TRIP signal lockout function set TripLockout Off and the automatic lockout function set AutoLock Off 12 11 1 5 Completing the test Continue to test another function or end the test by changing the TestMode setting to Off R...

Page 233: ...the pressure level input below PresAlmLimit check for PRES_ALM signal status in local HMI under Main menu Test Function status Monitoring Gas medium supervision SSIMG PRES_ALM 5 Activate BLOCK binary input the signals PRES_ALM PRES_LO should disappear 6 Reset the BLOCK binary input 7 Check for reset lock out input RESET_LO to reset PRES_LO lock out signal 8 Conduct these steps for temperature inpu...

Page 234: ...the BLOCK binary input 7 Check for reset lock out input RESET_LO to reset the LVL_LO lock out signal 8 Conduct these steps for temperature input as well to detect and reset TEMP_ALM and TEMP_LO signals 9 Continue to test another function or end the test by changing the TESTMODE setting to Off 12 12 2 2 Completing the test Continue to test another function or end the test by changing the TestMode s...

Page 235: ...heck the OPENPOS output by changing the POSOPEN to 1 and POSCLOSE to 0 and also inject the current in the selected phase slightly lower and higher than AccStopCurr set value Only for a current lower than set AccStopCurr should activate the output POSOPEN 5 4 Check the circuit breaker is in INVDPOS if auxiliary contacts read same value or CB is open and inject the current in selected phase more tha...

Page 236: ...ivated when NOOPER value exceeds the set OperAlmLevel value The actual value can be read on the output NOOPER 8 4 OPERLO is activated when NOOPER value exceeds the set OperLOLevel value 9 Test of CB spring charge monitoring 9 1 Test the actual set value defined by SpChAlmTime 9 2 Enable SPRCHRST input Also activate SPRCHRD after a time greater than set time SpChAlmTime 9 3 At this condition SPCHAL...

Page 237: ...result corresponds to the number of operations 12 12 5 1 Completing the test Continue to test another function or end the test by changing the Test mode setting to Off Restore connections and settings to their original values if they were changed for testing purposes 12 13 Metering 12 13 1 Pulse counter logic PCFCNT The test of the Pulse counter logic function PCFCNT requires the Parameter Setting...

Page 238: ... 10 Activate STOPACC input after some time and supply the IED with same current and voltage 11 Check that the ACCINPRG signal disappears immediately and EAFACC and ERFACC outputs also stop updating 12 Similarly the testing can be done for EAFACC and ERFACC outputs by changing the power inputs directions through direction settings Verification of MAXPAFD MAXPRFD outputs 1 Repeat the above test step...

Page 239: ...lues if they were changed for testing purposes 12 14 Station communication 12 14 1 Multiple command and transmit MULTICMDRCV MULTICMDSND The multiple command and transmit function MULTICMDRCV MULTICMDSND is only applicable for horizontal communication Test of the multiple command function block and multiple transmit is recommended to be performed in a system that is either in a complete delivery s...

Page 240: ...iagnostics Internal events Status for inputs and outputs Main menu Test Function status browse to the function group of interest Remote communication related signals Main menu Test Function status Communication Remote communication Test the correct functionality by simulating different kind of faults Also check that sent and received data is correctly transmitted and read A test connection is show...

Page 241: ... underMain menu Test Function status Setting groups ActiveGroup 3 Connect the appropriate dc voltage to the corresponding binary input of the IED and observe the information presented on the local HMI The displayed information must always correspond to the activated input 4 Check that the corresponding output indicates the active group Operating procedures for the PC aided methods of changing the ...

Page 242: ...nged for testing purposes 12 17 Exit test mode The following procedure is used to return to normal operation 1 Navigate to the test mode folder 2 Change the On setting to Off Press the E key and the left arrow key 3 Answer YES press the E key and exit the menus Section 12 1MRK502053 UEN B Testing functionality by secondary injection 236 Generator protection REG670 2 0 IEC Commissioning manual ...

Page 243: ...t the information given by the High speed distance protection ZMFPDIS ZMFCPDIS or the directional function ZDRDIR or ZDMRDIR whichever is used Procedure 1 Make sure that all control and protection functions that belong to the object that are going to be energized have been tested and are set to be in operation 2 Make sure that the primary load current fulfills the following conditions by using an ...

Page 244: ... not the same this is a sign of incorrect connection of the voltage or current transformers serving the distance protection function It is also possible that there is a wrong setting for the earthing point for one or more of the CTs serving distance protection the setting name is CTStarPoint available under the HMI menu Main menu Configuration Analog modules If the directional function shows forwa...

Page 245: ...X L3R L3X The measured impedance information can still be used to determine the direction of the load A positive resistance measured in all phases indicates a forward exporting resistive load active power while a negative sign indicates a reverse importing resistive load active power Usually it is enough to look at the resistive values to get information of the load direction that must anyway be c...

Page 246: ...240 ...

Page 247: ...e export or import of power available Finally final trip tests must be performed This involves activation of protection functions or tripping outputs with the circuit breaker closed and the tripping of the breaker verified When several breakers are involved each breaker must be checked individually and it must be verified that the other involved breakers are not tripped at the same time 14 2 Perio...

Page 248: ...de energized The IED cannot protect the circuit during testing Trained personnel may test one IED at a time on live circuits where redundant protection is installed and de energization of the primary circuit is not allowed ABB protection IEDs are preferably tested by aid of components from the COMBITEST testing system described in information B03 9510 E Main components are RTXP 8 18 24 test switch...

Page 249: ...y between obtained value and requested set value is too big the setting should be adjusted the new value recorded and a note should be made in the test record 14 2 2 4 Alarm test When inserting the test handle the alarm and event signalling is normally blocked This is done in the IED by setting the event reporting to Off during the test This can be done when the test handle is inserted or the IED ...

Page 250: ...to measure the service currents and service voltages recorded by the protection IED The service values are checked on the local HMI or in PCM600 Ensure that the correct values and angles between voltages and currents are recorded Also check the direction of directional functions such as Distance and directional overcurrent functions For transformer differential protection the achieved differential...

Page 251: ...l with a removed fuse or open miniature circuit breaker with an open connection wrong setting and so on Thus a list should be prepared of all items disturbed during test so that all can be put back into service quickly and without overlooking something It should be put back into service item by item and signed by the responsible engineer 1MRK502053 UEN B Section 14 Commissioning and maintenance of...

Page 252: ...246 ...

Page 253: ... signals Table 18 Signals from the General menu in the diagnostics tree Indicated result Possible reason Proposed action Internal fail Off No problem detected None Internal fail On A failure has occurred Check the rest of the indicated results to find the fault Internal warning Off No problem detected None Internal warning On A warning has been issued Check the rest of the indicated results to fin...

Page 254: ... in table 19 Table 19 Self supervision signals on the local HMI HMI Signal Name Status Description INT Fail OFF ON This signal will be active if one or more of the following internal signals are active INT LMDERROR INT WATCHDOG INT APPERROR INT RTEERROR or any of the HW dependent signals INT Warning OFF ON This signal will be active if one or more of the following internal signals are active INT R...

Page 255: ...NT FAIL and INT WARNING can be connected to binary output contacts for signalling to a control room In the IED Status Information the present information from the self supervision function can be viewed Indications of failure or warnings for each hardware module are provided as well as information about the external time synchronization and the internal clock All according to table 19 Loss of time...

Page 256: ... Error reset event ADMn Error ADMn Error set event MIM1 Error Off mA input module status MIM1 Error reset event MIM1 Error MIM1 Error set event INT RTC Off Real Time Clock RTC status INT RTC reset event INT RTC INT RTC set event INT TSYNC Off External time synchronization status INT TSYNC reset event INT TSYNC INT TSYNC set event INT SETCHGD Any settings in IED changed DRPC CLEARED All disturbance...

Page 257: ...on the workbench and connected to earth Disassemble and reassemble the IED accordingly 1 Switch off the dc supply 2 Short circuit the current transformers and disconnect all current and voltage connections from the IED 3 Disconnect all signal wires by removing the female connectors 4 Disconnect the optical fibers 5 Unscrew the main back plate of the IED 6 If the transformer module is to be changed...

Page 258: ... the ABB Logistic Center e mail offer selog se abb com 15 5 Maintenance The IED is self supervised No special maintenance is required Instructions from the power network company and other maintenance directives valid for maintenance of the power system must be followed Section 15 1MRK502053 UEN B Troubleshooting 252 Generator protection REG670 2 0 IEC Commissioning manual ...

Page 259: ...n Wire Gauge standard BBP Busbar protection BFOC 2 5 Bayonet fibre optic connector BFP Breaker failure protection BI Binary input BIM Binary input module BOM Binary output module BOS Binary outputs status BR External bistable relay BS British Standards BSR Binary signal transfer function receiver blocks BST Binary signal transfer function transmit blocks C37 94 IEEE ANSI protocol used when sending...

Page 260: ...sturbance recorder according to IEEE ANSI C37 111 1999 IEC 60255 24 Contra directional Way of transmitting G 703 over a balanced line Involves four twisted pairs two of which are used for transmitting data in both directions and two for transmitting clock signals COT Cause of transmission CPU Central processing unit CR Carrier receive CRC Cyclic redundancy check CROB Control relay output block CS ...

Page 261: ...tic discharge F SMA Type of optical fibre connector FAN Fault number FCB Flow control bit Frame count bit FOX 20 Modular 20 channel telecommunication system for speech data and protection signals FOX 512 515 Access multiplexer FOX 6Plus Compact time division multiplexer for the transmission of up to seven duplex channels of digital data over optical fibers FTP File Transfer Protocol FUN Function t...

Page 262: ... point to point communication IEC 61850 Substation automation communication standard IEC 61850 8 1 Communication protocol standard IEEE Institute of Electrical and Electronics Engineers IEEE 802 12 A network technology standard that provides 100 Mbits s on twisted pair or optical fiber cable IEEE P1386 1 PCI Mezzanine Card PMC standard for local bus modules References the CMC IEEE P1386 also known...

Page 263: ...ion according to IEC 60529 level 40 IP 54 Ingression protection according to IEC 60529 level 54 IRF Internal failure signal IRIG B InterRange Instrumentation Group Time code format B standard 200 ITU International Telecommunications Union LAN Local area network LIB 520 High voltage software module LCD Liquid crystal display LDCM Line differential communication module LDD Local detection device LED...

Page 264: ... card POR Permissive overreach POTT Permissive overreach transfer trip Process bus Bus or LAN used at the process level that is in near proximity to the measured and or controlled components PSM Power supply module PST Parameter setting tool within PCM600 PT ratio Potential transformer or voltage transformer ratio PUTT Permissive underreach transfer trip RASC Synchrocheck relay COMBIFLEX RCA Relay...

Page 265: ...d ring communication SRY Switch for CB ready condition ST Switch or push button to trip Starpoint Neutral point of transformer or generator SVC Static VAr compensation TC Trip coil TCS Trip circuit supervision TCP Transmission control protocol The most common transport layer protocol used on Ethernet and the Internet TCP IP Transmission control protocol over Internet Protocol The de facto standard...

Page 266: ...mination of standard frequencies and time signals UTC is derived from International Atomic Time TAI by the addition of a whole number of leap seconds to synchronize it with Universal Time 1 UT1 thus allowing for the eccentricity of the Earth s orbit the rotational axis tilt 23 5 degrees but still showing the Earth s irregular rotation on which UT1 is based The Coordinated Universal Time is express...

Page 267: ...261 ...

Page 268: ...r notice ABB AB does not accept any responsibility whatsoever for potential errors or possible lack of information in this document We reserve all rights in this document and in the subject matter and illustrations contained herein Any reproduction disclosure to third parties or utilization of its contents in whole or in part is forbidden without prior written consent of ABB AB Copyright 2014 ABB ...

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