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GE L90, Instruction Manual

The GE L90 is a high-performance electrical relay, designed to protect and control electrical power systems. Ensure proper installation and operation with the comprehensive, easy-to-follow Instruction Manual available for free download on our website. Access the manual today at manualshive.com and optimize your power system management effortlessly.

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L90 LINE CURRENT DIFFERENTIAL SYSTEM – INSTRUCTION MANUAL

FLEXANALOG ITEMS

APPENDIX A: FLEXANALOG OPERANDS

A

10248

SRC 1 Ia Harm[9]

%

Source 1 phase A current ninth harmonic

10249

SRC 1 Ia Harm[10]

%

Source 1 phase A current tenth harmonic

10250

SRC 1 Ia Harm[11]

%

Source 1 phase A current eleventh harmonic

10251

SRC 1 Ia Harm[12]

%

Source 1 phase A current twelfth harmonic

10252

SRC 1 Ia Harm[13]

%

Source 1 phase A current thirteenth harmonic

10253

SRC 1 Ia Harm[14]

%

Source 1 phase A current fourteenth harmonic

10254

SRC 1 Ia Harm[15]

%

Source 1 phase A current fifteenth harmonic

10255

SRC 1 Ia Harm[16]

%

Source 1 phase A current sixteenth harmonic

10256

SRC 1 Ia Harm[17]

%

Source 1 phase A current seventeenth harmonic

10257

SRC 1 Ia Harm[18]

%

Source 1 phase A current eighteenth harmonic

10258

SRC 1 Ia Harm[19]

%

Source 1 phase A current nineteenth harmonic

10259

SRC 1 Ia Harm[20]

%

Source 1 phase A current twentieth harmonic

10260

SRC 1 Ia Harm[21]

%

Source 1 phase A current twenty-first harmonic

10261

SRC 1 Ia Harm[22]

%

Source 1 phase A current twenty-second harmonic

10262

SRC 1 Ia Harm[23]

%

Source 1 phase A current twenty-third harmonic

10263

SRC 1 Ia Harm[24]

%

Source 1 phase A current twenty-fourth harmonic

10264

SRC 1 Ia Harm[25]

%

Source 1 phase A current twenty-fifth harmonic

10273

SRC 1 Ib THD

%

Source 1 phase B current total harmonic distortion

10274

SRC 1 Ib Harm[2]

%

Source 1 phase B current second harmonic

10275

SRC 1 Ib Harm[3]

%

Source 1 phase B current third harmonic

10276

SRC 1 Ib Harm[4]

%

Source 1 phase B current fourth harmonic

10277

SRC 1 Ib Harm[5]

%

Source 1 phase B current fifth harmonic

10278

SRC 1 Ib Harm[6]

%

Source 1 phase B current sixth harmonic

10279

SRC 1 Ib Harm[7]

%

Source 1 phase B current seventh harmonic

10280

SRC 1 Ib Harm[8]

%

Source 1 phase B current eighth harmonic

10281

SRC 1 Ib Harm[9]

%

Source 1 phase B current ninth harmonic

10282

SRC 1 Ib Harm[10]

%

Source 1 phase B current tenth harmonic

10283

SRC 1 Ib Harm[11]

%

Source 1 phase B current eleventh harmonic

10284

SRC 1 Ib Harm[12]

%

Source 1 phase B current twelfth harmonic

10285

SRC 1 Ib Harm[13]

%

Source 1 phase B current thirteenth harmonic

10286

SRC 1 Ib Harm[14]

%

Source 1 phase B current fourteenth harmonic

10287

SRC 1 Ib Harm[15]

%

Source 1 phase B current fifteenth harmonic

10288

SRC 1 Ib Harm[16]

%

Source 1 phase B current sixteenth harmonic

10289

SRC 1 Ib Harm[17]

%

Source 1 phase B current seventeenth harmonic

10290

SRC 1 Ib Harm[18]

%

Source 1 phase B current eighteenth harmonic

10291

SRC 1 Ib Harm[19]

%

Source 1 phase B current nineteenth harmonic

10292

SRC 1 Ib Harm[20]

%

Source 1 phase B current twentieth harmonic

10293

SRC 1 Ib Harm[21]

%

Source 1 phase B current twenty-first harmonic

10294

SRC 1 Ib Harm[22]

%

Source 1 phase B current twenty-second harmonic

10295

SRC 1 Ib Harm[23]

%

Source 1 phase B current twenty-third harmonic

10296

SRC 1 Ib Harm[24]

%

Source 1 phase B current twenty-fourth harmonic

10297

SRC 1 Ib Harm[25]

%

Source 1 phase B current twenty-fifth harmonic

10306

SRC 1 Ic THD

%

Source 1 phase C current total harmonic distortion

10307

SRC 1 Ic Harm[2]

%

Source 1 phase C current second harmonic

10308

SRC 1 Ic Harm[3]

%

Source 1 phase C current third harmonic

10309

SRC 1 Ic Harm[4]

%

Source 1 phase C current fourth harmonic

10310

SRC 1 Ic Harm[5]

%

Source 1 phase C current fifth harmonic

Address

FlexAnalog name

Units

Description

Summary of Contents for L90

Page 1: ...s Instruction Manual Product version 7 6x GE publication code 1601 0081 AF1 GEK 131004 L90 Line Current Differential System 1601 0081 AF1 IISO 9001 G N E I L M I U T L TE S I R G E E D R LISTED 52TL IND CONT EQ E83849 ...

Page 2: ...HardFiber Multilin and GE Multilin are trademarks or registered trademarks of GE Multilin Inc The contents of this manual are the property of GE Multilin Inc This documentation is furnished on license and may not be reproduced in whole or in part without the permission of GE Multilin The content of this manual is for informational use only and is subject to change without notice Part number 1601 0...

Page 3: ...y 2 8 2 4 Order codes 2 11 2 4 1 Order codes with enhanced CT VT modules 2 12 2 4 2 Order codes with process bus modules 2 19 2 4 3 Replacement modules 2 26 2 5 Signal processing 2 28 2 5 1 UR signal processing 2 28 2 6 Specifications 2 30 2 6 1 Protection elements 2 31 2 6 2 User programmable elements 2 40 2 6 3 Monitoring 2 42 2 6 4 Metering 2 43 2 6 5 Inputs 2 44 2 6 6 Power supply 2 45 2 6 7 O...

Page 4: ...er interface 3 42 3 4 8 IEEE C37 94 interface 3 43 3 4 9 C37 94SM interface 3 46 3 5 Activate relay 3 49 3 6 Install software 3 50 3 6 1 EnerVista communication overview 3 50 3 6 2 System requirements 3 51 3 6 3 Install software 3 51 3 7 Add device to software 3 52 3 7 1 Set IP address in UR 3 53 3 7 2 Configure serial connection 3 58 3 7 3 Configure Ethernet connection 3 59 3 7 4 Configure modem ...

Page 5: ...ic 4 76 4 4 4 View front panel and print labels 4 77 4 4 5 Generate connectivity report 4 78 4 4 6 Preferences 4 78 4 4 7 Toolbars 4 82 5 SETTINGS 5 1 Settings menu 5 1 5 2 Overview 5 4 5 2 1 Introduction to elements 5 4 5 2 2 Introduction to AC sources 5 6 5 3 Product setup 5 8 5 3 1 Security 5 8 5 3 2 Display properties 5 27 5 3 3 Graphical front panel 5 29 5 3 4 Clear relay records 5 41 5 3 5 C...

Page 6: ...9 Neutral current 5 267 5 7 10 Wattmetric ground fault 5 275 5 7 11 Ground current 5 279 5 7 12 Negative sequence current 5 286 5 7 13 Breaker failure ANSI 50BF 5 292 5 7 14 Voltage elements 5 302 5 7 15 Supervising elements 5 314 5 7 16 Sensitive directional power 5 321 5 8 Control elements 5 324 5 8 1 Overview 5 324 5 8 2 Trip bus 5 324 5 8 3 Setting groups 5 326 5 8 4 Selector switch 5 328 5 8 ...

Page 7: ...6 7 6 3 12 Digital counters 6 8 6 3 13 Selector switches 6 9 6 3 14 Flex states 6 9 6 3 15 Ethernet 6 9 6 3 16 Real time clock synchronizing 6 9 6 3 17 Remaining connection status 6 10 6 3 18 Parallel Redundancy Protocol PRP 6 11 6 3 19 TxGOOSE status 6 11 6 4 Metering 6 12 6 4 1 Metering conventions 6 12 6 4 2 Differential current 6 16 6 4 3 Sources 6 17 6 4 4 Sensitive directional power 6 23 6 4...

Page 8: ... point 8 4 8 2 6 CT tap 8 4 8 2 7 Breaker and a half 8 6 8 2 8 Distributed bus protection 8 9 8 3 Channel asymmetry compensation using GPS 8 10 8 3 1 Introduction 8 10 8 3 2 Compensation method 1 8 10 8 3 3 Compensation method 2 8 11 8 3 4 Compensation method 3 8 12 8 4 Distance backup supervision 8 13 8 4 1 Overview 8 13 8 4 2 Phase distance 8 14 8 4 3 Ground distance 8 15 8 5 Protection signalin...

Page 9: ...ets 10 11 10 1 14 Start up 10 12 10 1 15 Hardware and communication requirements 10 12 10 1 16 Online estimate of measurement errors 10 12 10 1 17 CT saturation detection 10 13 10 1 18 Charging current compensation 10 14 10 1 19 Differential element characteristics 10 15 10 1 20 Relay synchronization 10 16 10 2 Operating condition characteristics 10 17 10 2 1 Description 10 17 10 2 2 Trip decision...

Page 10: ...device 11 7 11 6 Compare settings 11 7 11 6 1 Compare against defaults 11 7 11 6 2 Compare two devices 11 8 11 7 Back up and restore settings 11 8 11 7 1 Back up settings 11 8 11 7 2 Restore settings 11 11 11 8 Upgrade software 11 13 11 9 Upgrade firmware 11 13 11 10 Replace front panel 11 15 11 11 Replace module 11 23 11 12 Battery 11 24 11 12 1 Replace battery for SH SL power supply 11 24 11 12 ...

Page 11: ... from high to low voltage circuits Use the device only for its intended purpose and application Ensure that all ground paths are uncompromised for safety purposes during device operation and service Ensure that the control power applied to the device the alternating current AC and voltage input match the ratings specified on the relay nameplate Do not apply current or voltage in excess of the spec...

Page 12: ...el are working on or around this primary equipment to prevent any inadvertent command from this device Use an external disconnect to isolate the mains voltage supply Personal safety can be affected if the product is physically modified by the end user Modifications to the product outside of recommended wiring configuration hardware or programming boundaries is not recommended end use practice Prod...

Page 13: ...CHAPTER 1 INTRODUCTION FOR FURTHER ASSISTANCE L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 1 3 1 Figure 1 1 Generate service report in EnerVista software ...

Page 14: ...1 4 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL FOR FURTHER ASSISTANCE CHAPTER 1 INTRODUCTION 1 ...

Page 15: ...citance can benefit from charging current compensation if terminal voltage measurements are applied to the relay The voltage input is also used for some protection and monitoring features such as directional elements fault locator metering and distance backup In addition the L90 provides local restricted ground fault protection The L90 operates over different communications links with various degr...

Page 16: ...sed from the front panel or EnerVista software The L90 uses flash memory technology that allows field upgrading as new features are added Firmware and software are upgradable The following single line diagram illustrates the relay functionality using American National Standards Institute ANSI device numbers Table 2 1 ANSI device numbers and functions supported Device number Function Device number ...

Page 17: ...hasor PMU Contact Outputs up to 72 IEC 61850 Communications Time synchronization over IRIG B or IEEE 1588 Control Pushbuttons IEC 62351 9 Data and Communications Security Time Synchronization over SNTP CT Failure Detector L90 Channel Tests Transducer Inputs Outputs CyberSentry Security Line Pickup User Definable Displays Data Logger Load Encroachment User Programmable LEDs Digital Counters 8 Meter...

Page 18: ...s via the communications channel Secure 32 bit CRC protection against communications errors Channel asymmetry up to 10 ms compensation using GPS satellite controlled clock 2 1 1 2 Backup protection DTT provision for pilot schemes Five zones of distance protection with six pilot schemes power swing blocking and out of step tripping line pickup and load encroachment Two element time overcurrent and ...

Page 19: ... first channel fails The L90 current differential relay is designed to function in a peer to peer or master to master architecture In the peer to peer architecture all relays in the system are identical and perform identical functions in the current differential scheme In order for every relay on the line to be a peer each relay must be able to communicate with all of the other relays If there is ...

Page 20: ...es DC offset from the current via the mimic algorithm Creates phaselets Calculates sum of squares data Transmits current data to all master L90 relays Performs all local relaying functions Receives current differential DTT and Direct Input signals from all other L90 relays Transmits direct output signals to all communicating relays Sends synchronization information of local clock to all other L90 ...

Page 21: ...ferential algorithm failure of the communications from a slave to the master prevents the master from performing the correct current differential logic Channel propagation delay is being continuously measured and adjusted according to changes in the communications path Every relay on the protection system can be assigned a unique ID to prevent advertent loopbacks at multiplexed channels 2 2 3 Loop...

Page 22: ...resent by default Two levels of password security are provided command and setting Use of a password for each level controls whether users can enter commands and or change settings The L90 supports password entry from a local or remote connection Local access is defined as any access to settings or commands via the front panel interface This includes both keypad entry and the through the front pan...

Page 23: ...ator functions or engineering type access all of which are defined by separate roles see figure so that access of UR devices by multiple personnel within a substation is allowed One role of one type is allowed to be logged in at a time For example one Operator can be logged in but not a second Operator at the same time This prevents subsets of settings from being changed at the same time Figure 2 ...

Page 24: ... Input threshold RW RW R R R Virtual Inputs RW RW R R R Contact Outputs RW RW R R R Virtual Outputs RW RW R R R Resetting RW RW R R R Direct Inputs RW RW R R R Direct Outputs RW RW R R R Teleprotection RW RW R R R Direct Analogs RW RW R R R Direct Integers RW RW R R R Transducer I O RW RW R R R Testing RW RW R R R Front Panel Labels Designer NA NA NA NA NA Protection Summary NA NA NA NA NA Command...

Page 25: ...nd not its local authentication database to authenticate the user No password or security information is displayed in plain text by the EnerVista software or UR device nor is such information ever transmitted without cryptographic protection CyberSentry server authentication The UR has been designed to direct automatically the authentication requests based on user names In this respect local accou...

Page 26: ...otection AR CyberSentry Lvl 1 IEC 61850 PMU and In zone transformer protection B0 IEEE 1588 B2 IEEE 1588 and Breaker and a half B3 IEEE 1588 and IEC 61850 B5 IEEE 1588 IEC 61850 and Breaker and a half B6 IEEE 1588 and PMU B7 IEEE 1588 IEC 61850 and PMU B8 IEEE 1588 PMU and Breaker and a half B9 IEEE 1588 IEC 61850 PMU and Breaker and a half BO IEEE 1588 and In zone transformer protection BP IEEE 1...

Page 27: ...tection IEC 61850 Breaker and a half and PMU HC IEEE 1588 CyberSentry Lvl 1 In zone transformer protection and Breaker and a half HD IEEE 1588 CyberSentry Lvl 1 In zone transformer protection IEC 61850 and Breaker and a half HE IEEE 1588 CyberSentry Lvl 1 In zone transformer protection Breaker and a half and PMU HF IEEE 1588 CyberSentry Lvl 1 In zone transformer protection IEC 61580 Breaker and a ...

Page 28: ...alf PMU 61850 90 5 MH IEEE 1588 In zone TX protection IEC 61850 PMU 61850 90 5 MJ PRP IEC 61850 PMU 61850 90 5 MK PRP IEC 61850 Breaker and Half PMU 61850 90 5 MN PRP In zone TX protection IEC 61850 PMU 61850 90 5 MP IEEE 1588 CyberSentry UR Lvl 1 IEC 61850 PMU 61850 90 5 MQ IEEE 1588 CyberSentry UR Lvl 1 IEC 61850 Breaker and Half PMU 61850 90 5 MT IEEE 1588 CyberSentry UR Lvl 1 In zone TX protec...

Page 29: ...A voltage with optional current and 4 Form C outputs 4 contact inputs 6C 6C 6C 6C 6C 8 Form C outputs 6D 6D 6D 6D 6D 16 Contact inputs 6E 6E 6E 6E 6E 4 Form C outputs 8 contact inputs 6F 6F 6F 6F 6F 8 Fast Form C outputs 6G 6G 6G 6G 6G 4 Form A voltage with optional current outputs 8 contact inputs 6H 6H 6H 6H 6H 6 Form A voltage with optional current outputs 4 contact inputs 6K 6K 6K 6K 6K 4 Form...

Page 30: ... and a half B6 IEEE 1588 and PMU B7 IEEE 1588 IEC 61850 and PMU B8 IEEE 1588 PMU and Breaker and a half B9 IEEE 1588 IEC 61850 PMU and Breaker and a half BO IEEE 1588 and In zone transformer protection BP IEEE 1588 IEC 61850 and In zone transformer protection BQ IEEE 1588 PMU and In zone transformer protection BR IEEE 1588 IEC 61850 PMU and In zone transformer protection C0 Parallel Redundancy Pro...

Page 31: ... PRP CyberSentry Lvl 1 In zone transformer protection Breaker and a half HP IEEE 1588 PRP CyberSentry Lvl 1 In zone transformer protection IEC 61850 Breaker and a half HQ IEEE 1588 PRP CyberSentry Lvl 1 In zone transformer protection breaker and a hal and PMU HR IEEE 1588 PRP CyberSentry Lvl 1 In zone Tx protection IEC 61850 breaker and a half and PMU HS IEC 60870 5 103 IEEE 1588 PRP In zone trans...

Page 32: ...play A Chinese display K Enhanced front panel with English display M Enhanced front panel with French display Q Enhanced front panel with Russian display U Enhanced front panel with Chinese display L Enhanced front panel with English display and user programmable pushbuttons N Enhanced front panel with French display and user programmable pushbuttons T Enhanced front panel with Russian display and...

Page 33: ...alf IEC 61850 communications and PMU 24 In zone transformer protection 25 In zone transformer protection and IEC 61850 26 In zone transformer protection and PMU 27 In zone transformer protection IEC 61850 and PMU 80 In zone transformer and Breaker and a half 81 In zone transformer IEC 61850 and Breaker and a half 82 In zone transformer Breaker and a half and PMU 83 In zone transformer IEC 61850 Br...

Page 34: ...4 IEEE 1588 In zone transformer protection and Breaker and a half H5 IEEE 1588 In zone transformer protection IEC 6850 and Breaker and a half H6 IEEE 1588 In zone transformer protection Breaker and a half and PMU H7 IEEE 1588 In zone transformer protection IEC 61850 Breaker and a half and PMU H8 PRP In zone transformer protection and Breaker and a half H9 PRP In zone transformer protection IEC 618...

Page 35: ... PMU 61850 90 5 ME IEEE 1588 IEC 61850 Breaker and Half PMU 61850 90 5 MH IEEE 1588 In zone TX protection IEC 61850 PMU 61850 90 5 MJ PRP IEC 61850 PMU 61850 90 5 MK PRP IEC 61850 Breaker and Half PMU 61850 90 5 MN PRP In zone TX protection IEC 61850 PMU 61850 90 5 MP IEEE 1588 CyberSentry UR Lvl 1 IEC 61850 PMU 61850 90 5 MQ IEEE 1588 CyberSentry UR Lvl 1 IEC 61850 Breaker and Half PMU 61850 90 5...

Page 36: ... C outputs 6D 6D 16 Contact inputs 6E 6E 4 Form C outputs 8 contact inputs 6F 6F 8 Fast Form C outputs 6G 6G 4 Form A voltage with optional current outputs 8 contact inputs 6H 6H 6 Form A voltage with optional current outputs 4 contact inputs 6K 6K 4 Form C and 4 Fast Form C outputs 6L 6L 2 Form A current with optional voltage and 2 Form C outputs 8 contact inputs 6M 6M 2 Form A current with optio...

Page 37: ... half and PMU C9 PRP IEC 61850 Breaker and a half and PMU CO PRP and In zone transformer protection CP PRP In zone transformer protection and IEC 61850 CQ PRP In zone transformer protection and PMU CR PRP In zone transformer protection IEC 61850 and PMU D0 IEEE 1588 and CyberSentry Lvl 1 D2 IEEE 1588 CyberSentry Lvl 1 and IEC 61850 D3 IEEE 1588 CyberSentry Lvl 1 and IEC 61850 D5 IEEE 1588 CyberSen...

Page 38: ...IEC 60870 5 103 IEEE 1588 PRP CyberSentry Lvl 1 In zone transformer protection Breaker and a half PMU HZ IEC 60870 5 103 IEEE 1588 PRP CyberSentry Lvl 1 In zone transformer protection IEC 61850 PMU J0 IEC 60870 5 103 J2 IEC 60870 5 103 Breaker and a half J3 IEC 60870 5 103 IEC 61850 J5 IEC 60870 5 103 IEC 61850 Breaker and a half J6 IEC 60870 5 103 PMU J7 IEC 60870 5 103 IEC 61850 PMU J8 IEC 60870...

Page 39: ...mmable pushbuttons POWER SUPPLY H 125 250 V AC DC power supply L 24 to 48 V DC only power supply PROCESS BUS MODULE 81 Eight port digital process bus module CONTACT INPUTS OUTPUTS XX XX XX XX No Module 4A 4 Solid State no monitoring MOSFET outputs 4B 4 Solid State voltage with optional current MOSFET outputs 4C 4 Solid State current with optional voltage MOSFET outputs 4D 16 Contact inputs with Au...

Page 40: ...y and user programmable pushbuttons 3I Enhanced front panel with German display 3J Enhanced front panel with German display and user programmable pushbuttons 3E 7 Graphical front panel display in multiple languages with USB front port and user programmable pushbuttons CONTACT INPUTS AND OUTPUTS 4A 4 Solid State no monitoring MOSFET outputs 4B 4 Solid State voltage with optional current MOSFET outp...

Page 41: ...hinese display and user programmable pushbuttons 3I Enhanced front panel with German display 3J Enhanced front panel with German display and user programmable pushbuttons CONTACT INPUTS OUTPUTS 4A 4 Solid State no monitoring MOSFET outputs 4B 4 Solid State voltage with optional current MOSFET outputs 4C 4 Solid State current with optional voltage MOSFET outputs 4D 16 Contact inputs with Auto Burni...

Page 42: ...ons and fixed in the hardware and thus is not dependent on the system nominal frequency setting 7D 1300 nm single mode Laser 1 Channel 7E Channel 1 G 703 Channel 2 820 nm multimode 7F Channel 1 G 703 Channel 2 1300 nm multimode 7G Channel 1 G 703 Channel 2 1300 nm single mode ELED 7H 820 nm multimode LED 2 Channels 7I 1300 nm multimode LED 2 Channels 7J 1300 nm single mode ELED 2 Channels 7K 1300 ...

Page 43: ...t 3840 Hz in 60 Hz systems and 3200 Hz in 50 Hz systems The sampling rate is dynamically adjusted to the actual system frequency by an accurate and fast frequency tracking system The A D converter has the following ranges of AC signals Voltages Eq 2 1 Currents Eq 2 2 Current harmonics are estimated based on raw samples with the use of the full cycle Fourier filter Harmonics 2nd through 25th are es...

Page 44: ...using a Finite Impulse Response FIR digital filter to remove high frequency noise contained in the signal The period is used after several security conditions are met such as true RMS signal must be above 6 nominal for a certain time and others If these security conditions are not met the last valid measurement is used for a specific time after which the UR reverts to nominal system frequency Sync...

Page 45: ...reverse or non directional Reach secondary Ω 0 02 to 500 00 Ω in steps of 0 01 Reach accuracy Zone 1 5 including the effect of CVT transients up to an SIR of 30 and 7 for 30 SIR 60 at RCA angle Zones 2 to 5 5 for steady fault conditions Distance Characteristic angle 30 to 90 in steps of 1 Comparator limit angle 30 to 90 in steps of 1 Directional supervision Characteristic angle 30 to 90 in steps o...

Page 46: ...n directional Reach secondary Ω 0 02 to 500 00 Ω in steps of 0 01 Reach accuracy Zone 1 5 including the effect of CVT transients up to an SIR of 30 and 7 for 30 SIR 60 at RCA angle Zones 2 to 5 5 for steady fault conditions Distance characteristic angle 30 to 90 in steps of 1 Distance comparator limit angle 30 to 90 in steps of 1 Directional supervision Characteristic angle 30 to 90 in steps of 1 ...

Page 47: ...30 000 pu Undervoltage pickup 0 004 to 3 000 pu Overvoltage delay 0 000 to 65 535 s LINE CURRENT DIFFERENTIAL 87L Application 2 or 3 terminal line series compensated line tapped line with charging current compensation Characteristic Dual slope percent differential Pickup current level 0 20 to 4 00 pu in steps of 0 01 CT Tap CT mismatch factor 0 20 to 5 00 in steps of 0 01 Slope 1 1 to 50 Slope 2 1...

Page 48: ... 5 of reading 2 0 CT rating Curve shapes IEEE Moderately Very Extremely Inverse IEC and BS A B C and Short Inverse GE IAC Inverse Short Very Extremely Inverse I2 t FlexCurves programmable Definite Time 0 01 s base curve Curve multiplier Time Dial 0 00 to 600 00 in steps of 0 01 Reset type Instantaneous Timed per IEEE Curve timing accuracy at 1 03 to 20 x pickup 3 5 of operate time or cycle whichev...

Page 49: ...hase seq phase A VBC phase B VCA phase C VAB ACB phase seq phase A VCB phase B VAC phase C VBA Polarizing voltage threshold 0 004 to 3 000 pu in steps of 0 001 Current sensitivity threshold 0 05 pu Characteristic angle 0 to 359 in steps of 1 Angle accuracy 2 Operation time FlexLogic operands Tripping reverse load forward fault 12 ms typically Blocking forward load reverse fault 8 ms typically NEUT...

Page 50: ...n steps of 0 001 Pickup level accuracy 1 or 0 001 pu whichever is greater Hysteresis 2 or 0 001 pu whichever is greater Pickup delay 0 to 600 00 s in steps of 0 01 Timer accuracy 3 of operate time or 1 4 cycle whichever is greater Operate time 50 ms PHASE UNDERVOLTAGE Voltage Phasor only Pickup level 0 004 to 3 000 pu in steps of 0 001 Dropout level 102 to 103 of pickup Level accuracy 0 5 of readi...

Page 51: ...o 98 of pickup Level accuracy 0 5 of reading from 10 to 208 V Pickup delay 0 to 600 00 s in steps of 0 01 Reset delay 0 to 600 00 s in steps of 0 01 Timer accuracy 3 of operate time or 1 4 cycle whichever is greater Operate time 30 ms at 1 10 pickup at 60 Hz VOLTS PER HERTZ Voltage Phasor only Pickup level 0 80 to 4 00 in steps of 0 01 pu V Hz Dropout level 97 to 98 of pickup Level accuracy 0 02 p...

Page 52: ... times are average operate times including variables such as frequency change instance test method and so on and can vary by 0 5 cycles BREAKER FAILURE Mode 1 pole 3 pole Current supervision phase neutral current Current supv pickup 0 020 to 30 000 pu in steps of 0 001 Current supv dropout 97 to 98 of pickup Current supv accuracy 0 1 to 2 0 CT rating 0 75 of reading or 2 of rated whichever is grea...

Page 53: ...ransfer Trip POTT Hybrid POTT Scheme Directional Comparison Blocking Scheme Directional Comparison Unblocking Scheme DCUB TRIP OUTPUT Collects trip and reclose input requests and issues outputs to control tripping and reclosing Communications timer delay 0 to 65535 s in steps of 0 001 Evolving fault timer 0 000 to 65 535 s in steps of 0 001 Timer accuracy 3 of operate time or 1 4 cycle whichever i...

Page 54: ... Reset time constant 0 to 1000 min in steps of 1 Minimum reset time 0 to 1000 min in steps of 1 Timer accuracy cold curve 100 ms or 2 whichever is greater Timer accuracy hot curve 500 ms or 2 whichever is greater for Ip 0 9 k Ib and I k Ib 1 1 TRIP BUS TRIP WITHOUT FLEXLOGIC Number of elements 6 Number of inputs 16 Operate time 2 ms at 60 Hz Timer accuracy 3 or 10 ms whichever is greater 2 6 2 Use...

Page 55: ...e 1 all LEDs on Test sequence 2 all LEDs off one LED at a time on for 1 s Test sequence 3 all LEDs on one LED at a time off for 1 s USER DEFINABLE DISPLAYS Enhanced and standard front panels Number of displays 16 Lines of display 2 20 alphanumeric characters Parameters up to 5 any Modbus register addresses Invoking and scrolling keypad or any user programmable condition including pushbuttons CONTR...

Page 56: ...DATA LOGGER Number of channels 1 to 16 Parameters any available analog actual value Sampling rate 15 to 3600000 ms in steps of 1 Trigger any FlexLogic operand Mode continuous or triggered Storage capacity NN is dependent on memory 1 second rate 01 channel for NN days 16 channels for NN days 60 minute rate 01 channel for NN days 16 channels for NN days FAULT LOCATOR Number of independent fault loca...

Page 57: ...y 0 5 of reading from 10 to 208 V REAL POWER WATTS Accuracy at 0 1 to 1 5 x CT rating and 0 8 to 1 2 x VT rating 1 0 of reading at 1 0 PF 0 8 and 0 8 PF 10 REACTIVE POWER VARS Accuracy at 0 1 to 1 5 x CT rating and 0 8 to 1 2 x VT rating 1 0 of reading at 0 2 PF 0 2 APPARENT POWER VA Accuracy at 0 1 to 1 5 x CT rating and 0 8 to 1 2 x VT rating 1 0 of reading WATT HOURS POSITIVE AND NEGATIVE Accur...

Page 58: ... range Standard CT 0 02 to 46 CT rating RMS symmetrical Sensitive Ground CT module 0 002 to 4 6 CT rating RMS symmetrical Current withstand 20 ms at 250 times rated 1 sec at 100 times rated continuous 4xInom Short circuit rating 150000 RMS symmetrical amperes 250 V maximum primary current to external CT AC VOLTAGE VT rated secondary 50 0 to 240 0 V VT ratio 1 00 to 24000 00 Relay burden 0 25 VA at...

Page 59: ...6 V pk pk IRIG B INPUT IRIG formats accepted B000 B007 B120 B127 IRIG control bits IEEE Std C37 118 1 2011 Amplitude modulation 1 to 10 V pk pk DC shift TTL Compatible Input impedance 50 kΩ Isolation 2 kV 2 6 6 Power supply LOW RANGE Nominal DC voltage 24 to 48 V Minimum DC voltage 20 V Maximum DC voltage 75 V for SL power supply module Voltage loss hold up 200 ms duration at maximum load NOTE Low...

Page 60: ... continuous 6 A as per IEEE C37 90 Break DC resistive as per IEC61810 1 Operate time 4 ms Contact material silver alloy Control separate operate and reset inputs Control mode operate dominant or reset dominant FORM A VOLTAGE MONITOR Applicable voltage approx 15 to 250 V DC Trickle current approx 1 to 2 5 mA FORM A CURRENT MONITOR Threshold current approx 80 to 100 mA FORM C AND CRITICAL FAILURE RE...

Page 61: ... 20 mA Max load resistance 12 kΩ for 1 to 1 mA range 12 kΩ for 0 to 1 mA range 600 Ω for 4 to 20 mA range Accuracy 0 75 of full scale for 0 to 1 mA range 0 5 of full scale for 1 to 1 mA range 0 75 of full scale for 0 to 20 mA range 99 Settling time to a step change 100 ms Isolation 1 5 kV Input voltage Impedance 2 W Resistor 1 W Resistor 250 V DC 20 KΩ 50 KΩ 120 V DC 5 KΩ 2 KΩ 48 V DC 2 KΩ 2 KΩ 24...

Page 62: ... 2 kV isolated together at 36 Vpk FIBER ETHERNET PORT ETHERNET 10 100 MB TWISTED PAIR Modes 10 Mb 10 100 Mb auto detect Connector RJ45 SIMPLE NETWORK TIME PROTOCOL SNTP Clock synchronization error 10 ms typical PRECISION TIME PROTOCOL PTP PTP IEEE Std 1588 2008 version 2 Power Profile PP per IEEE Standard PC37 238TM2011 Slave only ordinary clock Peer delay measurement mechanism PARALLEL REDUNDANCY...

Page 63: ...m 16 dBm 32 dBm 16 dBm 8 dBm 50 125 μm 20 dBm 12 dBm 1300 nm Single mode 9 125 μm 15 dBm 32 dBm 17 dBm 8 dBm 1300 nm Laser Single mode 9 125 μm 0 dBm 34 dBm 34 dBm 8 dBm 1550 nm Laser Single mode 9 125 μm 5 dBm 34 dBm 39 dBm 10 dBm Emitter fiber type Transmit power Received sensitivity Power budget Maximum optical input power 820 nm LED Multimode 20 dBm 30 dBm 10 dB 7 6 dBm 1300 nm LED Multimode 2...

Page 64: ...Resolution 800 by 480 pixels Pages 5 single line diagram pages with controls status and metering values up to 8 annunciator pages with total of 96 annunciator windows 1 phasor metering page for each AC Source 5 tabular metering pages with dynamic metering and status event records page with dynamic update product information page settings actual values error messages targets Emitter fiber type Cabl...

Page 65: ...ons for power system element control RESET pushbutton 8 physical user programmable pushbuttons 8 graphical interface pushbuttons INGRESS PROTECTION IP code IP20 front IP54 front with graphical front panel IP10 back 2 6 12 Environmental AMBIENT TEMPERATURES Storage temperature 40 to 85 C Operating temperature 40 to 60 C the LCD contrast can be impaired at temperatures less than 20 C HUMIDITY Humidi...

Page 66: ...e interruption and ripple DC IEC 60255 11 12 ripple 200 ms interrupts Radiated and conducted emissions CISPR11 CISPR22 IEC 60255 25 Class A Sinusoidal vibration IEC 60255 21 1 Class 1 Shock and bump IEC 60255 21 2 Class 1 Seismic IEC 60255 21 3 Class 1 Power magnetic immunity IEC 61000 4 8 Level 5 Pulse magnetic immunity IEC 61000 4 9 Level 4 Damped magnetic immunity IEC 61000 4 10 Level 4 Voltage...

Page 67: ...CLEANING Normally cleaning is not required When dust has accumulated on the front panel display wipe with a dry cloth Compliance Applicable council directive According to CE Low voltage directive EN 60255 5 EMC directive EN 60255 26 EN 50263 EN 61000 6 5 C UL US UL 508 UL 1053 C22 2 No 14 To avoid deterioration of electrolytic capacitors power up units that are stored in a de energized state once ...

Page 68: ...2 54 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL SPECIFICATIONS CHAPTER 2 PRODUCT DESCRIPTION 2 ...

Page 69: ...ed copy if ordered UR Family Communications Guide soft copy on DVD printed copy if Instruction Manual ordered Certificate of Calibration Test Report EC Declaration of Conformity Front panel label package 2 Inspect the unit for physical damage 3 View the rear nameplate and verify that the correct model has been delivered The model number is at the top right 4 Any protective plastic film on the fron...

Page 70: ...d at the time of ordering The enhanced front panel contains additional user programmable pushbuttons and LED indicators The modular design allows the relay to be upgraded and repaired by qualified service personnel The front panel is hinged to allow access to the removable modules and is itself removable to allow mounting on doors with limited rear depth The case dimensions are shown in the follow...

Page 71: ...3 INSTALLATION PANEL CUTOUTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 3 3 3 Figure 3 1 Horizontal dimensions enhanced front panel Figure 3 2 Horizontal mounting enhanced and graphical front panel ...

Page 72: ...INE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL PANEL CUTOUTS CHAPTER 3 INSTALLATION 3 Figure 3 3 Horizontal mounting and dimensions standard front panel Figure 3 4 Horizontal dimension graphical front panel ...

Page 73: ...nel The front panel is hinged to allow easy access to the removable modules and is itself removable to allow mounting on doors with limited rear depth The case dimensions are shown in the following figure along with panel cutout details for panel mounting When planning the location of your panel cutout ensure that provision is made for the front panel to swing open without interference to or from ...

Page 74: ...3 6 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL PANEL CUTOUTS CHAPTER 3 INSTALLATION 3 Figure 3 5 Vertical dimensions enhanced front panel ...

Page 75: ...he enhanced front panel see the following documents available on the UR DVD and the GE Grid Solutions website GEK 113180 UR Series UR V Side Mounting Front Panel Assembly Instructions GEK 113181 Connecting a Remote UR V Enhanced Front Panel to a Vertical UR Device Instruction Sheet GEK 113182 Connecting a Remote UR V Enhanced Front Panel to a Vertically Mounted Horizontal UR Device Instruction She...

Page 76: ...ERENTIAL SYSTEM INSTRUCTION MANUAL PANEL CUTOUTS CHAPTER 3 INSTALLATION 3 For side mounting L90 devices with the standard front panel use the following figures Figure 3 7 Vertical side mounting installation standard front panel ...

Page 77: ...CHAPTER 3 INSTALLATION PANEL CUTOUTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 3 9 3 Figure 3 8 Vertical side mounting rear dimensions standard front panel ...

Page 78: ... arrow marker on the terminal block The figure shows an example of rear terminal assignments Do not touch any rear terminals while the relay is energized else death or serious injury can result from electrical shock The small form factor pluggable ports SFPs are pluggable transceivers They transmit and receive and convert electrical signals to optical signals and vice versa They are inserted into ...

Page 79: ...pounds For the screws used to wire the terminal blocks rows 1 to 8 use 19 1 inch pounds During manufacturing the power supply and CPU modules are installed in slots B and D of the chassis with 13 inch pounds of torque on the screws at the top and bottom of the modules Wire connections to these two modules at 13 inch pounds Figure 3 10 CPU modules and power supply The following figure shows the opt...

Page 80: ...3 12 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL WIRING CHAPTER 3 INSTALLATION 3 3 3 Wiring 3 3 1 Typical wiring Figure 3 12 Typical wiring diagram T module shown for CPU ...

Page 81: ...becomes faulted the second power supply assumes the full load of the relay without any interruptions Each power supply has a green LED on the front of the module to indicate that it is functional The critical fail relay of the module also indicates a faulted power supply Module type Module function Terminals Dielectric strength From To 1 Power supply High Low Chassis 2000 V AC for 1 minute 1 Power...

Page 82: ...e channels are intended for connection to a CT between system neutral and ground and are labelled as ground current IG To connect the module size 12 American Wire Gauge AWG is used commonly the maximum size is 10 AWG CT VT modules can be ordered with a standard ground current input that is the same as the phase current input Each AC current input has an isolating transformer and an automatic short...

Page 83: ...sequence CT is recommended Figure 3 14 Zero sequence core balance CT installation The phase voltage channels are used for most metering and protection purposes The auxiliary voltage channel is used as input for the synchrocheck and volts per hertz features which are optional features available for some UR models Figure 3 15 CT VT module wiring Substitute the tilde symbol with the slot position of ...

Page 84: ...two inputs per common return When a contact input output module is ordered four inputs per common is used If the inputs must be isolated per row then two inputs per common return are selected 4D module The tables and diagrams on the following pages illustrate the module types 6A and so on and contact arrangements that can be ordered for the relay Since an entire row is used for a single contact ou...

Page 85: ... OF FORM A AND SOLID STATE RELAY OUTPUTS IN HIGH IMPEDANCE CIRCUITS For form A and solid state relay output contacts internally equipped with a voltage measuring circuit across the contact the circuit has an impedance that can cause a problem when used in conjunction with external high input impedance monitoring equipment such as modern relay test set trigger circuits These monitoring circuits can...

Page 86: ...8a 8c 2 Inputs 8a 8c 2 Inputs 8 Form C 8a 8c 2 Inputs 6E module 6F module 6G module 6H module Terminal assignment Output or input Terminal assignment Output Terminal assignment Output or input Terminal assignment Output or input 1 Form C 1 Fast Form C 1 Form A 1 Form A 2 Form C 2 Fast Form C 2 Form A 2 Form A 3 Form C 3 Fast Form C 3 Form A 3 Form A 4 Form C 4 Fast Form C 4 Form A 4 Form A 5a 5c 2...

Page 87: ...ssignment Output Terminal assignment Output 1 Form A 1 Form A 1 Form A 1 Not Used 2 Form A 2 Form A 2 Form A 2 Solid State 3 Form A 3 Form C 3 Form A 3 Not Used 4 Form A 4 2 Outputs 4 Form A 4 Solid State 5 Form A 5a 5c 2 Inputs 5 Form A 5 Not Used 6 Form A 6a 6c 2 Inputs 6 Form A 6 Solid State 7a 7c 2 Inputs 7a 7c 2 Inputs 7 Form A 7 Not Used 8a 8c 2 Inputs 8a 8c 2 Inputs 8 Form A 8 Solid State 4...

Page 88: ...3 20 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL WIRING CHAPTER 3 INSTALLATION 3 Figure 3 17 Contact input and output module wiring Sheet 1 of 2 ...

Page 89: ... LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 3 21 3 Figure 3 18 Contact input and output module wiring Sheet 2 of 2 For proper functionality observe the polarity shown in the figures for all contact input and output connections ...

Page 90: ...urces 84 V DC for 110 to 125 V sources and 166 V DC for 250 V sources Figure 3 19 Dry and wet contact input connections There is no provision in the relay to detect a DC ground fault on 48 V DC control power external output We recommend using an external DC supply 3 3 6 2 General application considerations Contacts outputs of protective relays auxiliary contacts from breakers disconnectors and oth...

Page 91: ...apacitance and the input impedance of the contact input If the duration is greater than the debounce time setting then the contact input operates The application example that follows describes how to mitigate this problem by connecting a resistor across the contact input as shown in the next figure or by adjusting the debounce time setting to a value greater than the discharge time to prevent spur...

Page 92: ...t debounce time as per the following table or insert a resistor less than or equal to R as calculated later Table 3 5 Typical debounce time setting Default debounce time on contact inputs is 6 ms The value of this resistor R is calculated as follows 1 Determine the minimum voltage V threshold required to turn on the input This is determined by direct measurement or referenced in the input specific...

Page 93: ...hreshold is reached to burn off this oxidation layer as a maintenance to the contacts Afterwards the contact input current is reduced to a steady state current The impulse has a five second delay after a contact input changes state Figure 3 22 Current through contact inputs with auto burnishing Regular contact inputs limit current to less than 3 mA to reduce station battery burden In contrast cont...

Page 94: ...ng OFF contact state non activated condition During Low impedance state contact input impedance is maintained at 10 K Ohms impedance to allow fast discharge of the stray capacitance of the long cables When the contact input voltage exceeds the set threshold active impedance maintains 10 K Ohms impedance value If voltage starts rapidly decreasing this indicates that stray capacitance is being disch...

Page 95: ...in the relay to drive the analog outputs Every transducer input output module has a total of 24 terminal connections These connections are arranged as three terminals per row with a total of eight rows A given row can be used for either inputs or outputs with terminals in column a having positive polarity and terminals in column c having negative polarity Since an entire row is used for a single i...

Page 96: ...NTIAL SYSTEM INSTRUCTION MANUAL WIRING CHAPTER 3 INSTALLATION 3 Figure 3 25 Transducer input output module wiring The following figure show how to connect RTDs Where a tilde symbol appears substitute the slot position of the module ...

Page 97: ...erial port is located on the front panel for programming with a computer All that is required to use this interface is a computer running the EnerVista UR Setup software provided with the relay Cabling for the RS232 port is shown in the following figure for both 9 pin and 25 pin connectors The baud rate for this port can be set with a default of 115200 bps ...

Page 98: ...IRING CHAPTER 3 INSTALLATION 3 Figure 3 27 RS232 front panel port connection 3 3 9 CPU communication ports 3 3 9 1 Overview In addition to the front panel RS232 port there is a rear RS485 communication port The CPU modules do not require a surge ground connection ...

Page 99: ...als connected together and all RS485 terminals connected together Though data is transmitted over a two wire twisted pair all RS485 devices require a shared reference or common voltage This common voltage is implied to be a power supply common Some systems allow the shield drain wire to be used as common wire and to connect directly to the L90 COM terminal 3 others function correctly only if the c...

Page 100: ...l connection 3 3 9 3 100Base FX fiber optic ports The fiber optic communication ports allow for fast and efficient communications between relays at 100 Mbps Optical fiber can be connected to the relay supporting a wavelength of 1310 nm in multimode Ensure that the dust covers are installed when the fiber is not in use Dirty or scratched connectors can lead to high losses on a fiber link 3 3 10 IRI...

Page 101: ... relay communications modules are available with several interfaces and some are outlined here in more detail Those that apply depend on options purchased The options are outlined in the Inter Relay Communications section of the Order Code tables in Chapter 2 Using an amplitude modulated receiver causes errors up to 1 ms in event time stamping When IRIG B is used as the time synchronization source...

Page 102: ...ber modules 3 4 2 Fiber laser transmitters The following figure shows the configuration for the 72 73 7D and 7K fiber laser modules Figure 3 32 7x Laser fiber modules The following figure shows configuration for the 2I and 2J fiber laser modules The current differential function must be Enabled for the communications module to properly operate See the SETTINGS GROUPED ELEMENTS LINE DIFFERENTIAL CU...

Page 103: ...or X6a grounds the shield since these pins are connected internally to ground Thus if pin X1a or X6a is used to ground the shield at one end do not ground the shield at the other end This interface module is protected by surge suppression devices Figure 3 34 G 703 interface configuration The following figure shows the typical pin interconnection between two G 703 interfaces For the actual physical...

Page 104: ... the module cover screw 4 Remove the top cover by sliding it towards the rear and then lift it upwards 5 Set the timing selection switches channels 1 and 2 to the required timing modes 6 Replace the top cover and the cover screw 7 Re insert the G 703 module Take care to ensure that the correct module type is inserted into the correct slot position The ejector inserter clips located at the top and ...

Page 105: ...e set the G 703 timing selection to internal timing mode for back to back UR to UR connections For back to back connections set octet timing S1 OFF and timing mode to internal timing S5 ON and S6 OFF Loop Timing Mode The system clock is derived from the received line signal Therefore set the G 703 timing selection to loop timing mode for connections to higher order systems For connection to a high...

Page 106: ...g is returned as it is received the timing source is expected to be from the G 703 line side of the interface Figure 3 38 G 703 minimum remote loopback mode In dual loopback mode the multiplexers are active and the functions of the circuit are divided into two with each receiver transmitter pair linked together to deconstruct and then reconstruct their respective signals Differential Manchester da...

Page 107: ...pedance with the impedance of the line Figure 3 40 RS422 interface connections The following figure shows the typical pin interconnection between two single channel RS422 interfaces installed in slot W All pin interconnections are to be maintained for a connection to a multiplexer Figure 3 41 Typical pin interconnection between two RS422 interfaces 3 4 4 2 Two channel application via multiplexers ...

Page 108: ...n the send timing outputs of data module 1 are also paralleled to the terminal timing inputs of data module 2 By using this configuration the timing for both data modules and both UR RS422 channels are derived from a single clock source As a result data sampling for both of the UR RS422 channels is synchronized via the send timing leads on data module 1 shown as follows If the terminal timing feat...

Page 109: ...of the Tx data bit Figure 3 43 Clock and data transitions 3 4 4 4 Receive timing The RS422 interface utilizes NRZI MARK modulation code and therefore does not rely on an Rx clock to recapture data NRZI MARK is an edge type invertible self clocking code To recover the Rx clock from the data stream an integrated digital phase lock loop DPLL circuit is utilized The DPLL is driven by an internal clock...

Page 110: ...e connection The connections shown in the figure are for multiplexers configured as data communications equipment DCE units 3 4 7 G 703 and fiber interface The following figure shows the combined G 703 plus fiberoptic interface configuration at 64 kbps The 7E 7F 7G 7Q and 75 modules are used in configurations where channel 1 is employed via the G 703 interface possibly with a multiplexer and chann...

Page 111: ...704 pattern from the standpoint of framing and data rate The frame is 256 bits and is repeated at a frame rate of 8000 Hz with a resultant bit rate of 2048 kbps The specifications for the module are as follows IEEE standard C37 94 for 2 64 kbps optical fiber interface for 76 and 77 modules Fiber optic cable type 50 nm or 62 5 μm core diameter optical fiber Fiber optic mode multimode Fiber optic ca...

Page 112: ...lay 1 and loop timed for relay 2 There must be only one timing source configured For the looped timing mode the system clock is derived from the received line signal Therefore set the timing selection to loop timing mode for connections to higher order systems The IEEE C37 94 communications module cover removal procedure is as follows 1 With power to the relay off remove the IEEE C37 94 module typ...

Page 113: ...e 3 50 IEEE C37 94 timing selection switch setting Modules shipped since January 2012 have status LEDs that indicate the status of the DIP switches as shown in the following figure Figure 3 51 Status LEDs The clock configuration LED status is as follows Flashing green loop timing mode while receiving a valid data packet ...

Page 114: ...andpoint of framing and data rate The frame is 256 bits and is repeated at a frame rate of 8000 Hz with a resultant bit rate of 2048 kbps The specifications for the module are as follows Emulated IEEE standard Emulates C37 94 for 1 64 kbps optical fiber interface modules set to n 1 or 64 kbps Fiber optic cable type 9 125 μm core diameter optical fiber Fiber optic mode Single mode ELED compatible w...

Page 115: ...edure is as follows 1 With power to the relay off remove the C37 94SM module module 2A or 2B as follows Record the original location of the module to help ensure that the same or replacement module is inserted into the correct slot 2 Simultaneously pull the ejector inserter clips located at the top and at the bottom of each module in order to release the module for removal 3 Remove the module cove...

Page 116: ...ure 3 53 C37 94SM timing selection switch setting Modules shipped since January 2012 have status LEDs that indicate the status of the DIP switches as shown in the following figure Figure 3 54 Status LEDs The clock configuration LED status is as follows Flashing green loop timing mode while receiving a valid data packet ...

Page 117: ...he MENU key until the SETTINGS header flashes momentarily and the PRODUCT SETUP message displays 2 Press the MESSAGE right arrow until the SECURITY message displays 3 Press the MESSAGE down arrow until the INSTALLATION message displays 4 Press the MESSAGE right arrow until the RELAY SETTINGS Not Programmed message displays 5 After the RELAY SETTINGS Not Programmed message displays press a VALUE ke...

Page 118: ...o the relay and the DB 9 or DB 25 female end to the computer COM2 port as described in the CPU Communication Ports section earlier in this chapter Figure 3 55 Relay communication options To communicate through the L90 rear RS485 port from a computer RS232 port the GE Grid Solutions RS232 RS485 converter box is required This device catalog number F485 connects to the computer using a straight throu...

Page 119: ...l the software From the DVD Download EnerVista Launchpad software from http www gegridsolutions com multilin and install it Download the EnerVista UR Setup software from http www gegridsolutions com multilin and install it To install the software from the DVD and using EnerVista Launchpad 1 Insert the DVD into the DVD drive of your computer 2 Click the Install Now button and follow the instruction...

Page 120: ...IEDs in the EnerVista Launchpad window as shown Figure 3 58 UR device added to Launchpad window 3 7 Add device to software You connect remotely to the L90 through the rear RS485 or Ethernet port with a computer running the EnerVista UR Setup software The L90 also can be accessed locally with a computer through the front panel RS232 port or the rear Ethernet port using the Quick Connect feature The...

Page 121: ... communication For serial communication for example using the front RS232 port and the Quick Connect feature the addresses are not required but typically they are entered to add configure devices for regular use 1 On the front of the L90 press the MENU key until the Settings menu displays 2 Navigate to Settings Product Setup Communications Network IP Address Setting 3 Enter an IP address for examp...

Page 122: ... SYSTEM INSTRUCTION MANUAL ADD DEVICE TO SOFTWARE CHAPTER 3 INSTALLATION 3 connections window Or in Windows 7 access the Network and Sharing Center in the Control Panel 2 Right click the Local Area Connection icon and select Properties ...

Page 123: ...he Start button and entering cmd 2 Type the following command substituting the IP address of 1 1 1 1 with yours C WINNT ping 1 1 1 1 3 If the connection is successful the system returns four replies similar to the following Pinging 1 1 1 1 with 32 bytes of data Reply from 1 1 1 1 bytes 32 time 10ms TTL 255 Reply from 1 1 1 1 bytes 32 time 10ms TTL 255 Reply from 1 1 1 1 bytes 32 time 10ms TTL 255 ...

Page 124: ...e PRODUCT SETUP COMMUNICATIONS NETWORK IP ADDRESS setting then repeat step 2 7 If the following sequence of messages appears when entering the C WINNT ping 1 1 1 1 command Pinging 1 1 1 1 with 32 bytes of data Destination host unreachable Destination host unreachable Destination host unreachable Destination host unreachable Ping statistics for 1 1 1 1 Packets Sent 4 Received 0 Lost 4 100 loss Appr...

Page 125: ...ess assigned to the L90 then click the Connect button The EnerVista UR Setup software creates a site named Quick Connect with a corresponding device also named Quick Connect and displays them on the left side of the screen 5 Expand the sections to view data directly from the L90 device Each time that the EnerVista UR Setup software is initialized click the Quick Connect button to establish direct ...

Page 126: ...etails 1 Connect the computer to the F485 and the F485 to the RS485 terminal on the back of the UR device Or connect directly the computer to the RS232 port on the front of the relay 2 Start the EnerVista UR Setup software or in EnerVista Launchpad select the UR device to start the software 3 Click the Add Site button A new category is added 4 Enter a site name in the Site Name field Optionally ad...

Page 127: ...L 2030 or SEL 2032 This option enables display of a terminal window to allow interaction with the other device 11 Click the Read Order Code button to connect to the L90 and upload the order code to the software If a communications error occurs ensure that the EnerVista software serial communications values entered in the previous step correspond to the relay setting values and also ensure that the...

Page 128: ...t be entered for Ethernet functionality Figure 3 61 Configuring Ethernet communication 10 Enter the relay IP Address which can be viewed on the device front panel under SETTINGS PRODUCT SETUP COMMUNICATIONS NETWORK IP ADDRESS Once the IP address is entered try to load automatically the device information by clicking the Read Order Code button 11 Enter the relay Slave address and Modbus Port addres...

Page 129: ...h communication with the remote modem Post Terminal Window Enable this option if you have a SEL 203x Communications Processor such as an SEL 2030 or SEL 2032 It enables display of a terminal window to allow interaction with the other device 12 Once the phone number is entered try to load automatically the device information by clicking the Read Order Code button 13 Click the OK button when the rel...

Page 130: ...e that the same IP address is not assigned to multiple L90 ports for example under Settings Product Setup Communications Network 3 8 1 Connect to the L90 in EnerVista For information on using the EnerVista software see the Interfaces chapter To access the relay in EnerVista 1 Open the Settings Product Setup Display Properties window as shown The window opens with a status indicator on the lower le...

Page 131: ... online window users can select the relay to interrogate from a pull down window then click the button for the action to perform The following quick action functions are available View the event record View the last recorded oscillography record View the status of all L90 inputs and outputs View all of the L90 metering values View the L90 protection summary Generate a service report 3 8 2 Use Quic...

Page 132: ...to establish direct communications to the L90 This ensures that configuration of the EnerVista UR Setup software matches the L90 model number 3 8 3 Use Quick Connect via a rear Ethernet port To connect to a UR using an Ethernet cable 1 In the EnerVista software click the Quick Connect button The window opens 2 Select the Ethernet interface and enter the IP address assigned to the L90 then click th...

Page 133: ...ion is supported When Server authentication is required characteristics for communication with a RADIUS server must be configured on the UR This is possible only through the EnerVista software The RADIUS server itself also must be configured At the end of this instruction manual the appendix called RADIUS Server gives an example of how to set up a simple RADIUS server Once both the RADIUS server a...

Page 134: ...for configuration details to achieve it A UR in the substation can authenticate a user either connecting to a RADIUS server or on the device itself This depends on the user name used for authentication on a connection The D400 connects to the UR device using the rear Ethernet or serial port The Ethernet connection can be ST or RJ 45 type The serial connection can be RS232 or RS485 At the other end...

Page 135: ... changed Saved with a _YYMMDDhhmmss retrieval time stamp for example SETTING_CHANGES_170525183124 TXT 3 11 4 Setting files These are the configuration settings files in the IEC 61850 SCL IID format The ur iid file is saved with a _YYMMDDhhmmss retrieval time stamp for example ur_170525183124 iid It is stored in the D400 folder system using the UR site and device name ...

Page 136: ...3 68 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL CONNECT TO D400 GATEWAY CHAPTER 3 INSTALLATION 3 ...

Page 137: ...r outlines the EnerVista software interface features The EnerVista UR Setup Help File also provides details for getting started and using the software interface 4 1 2 Settings files The EnerVista software supports the following three ways of handling changes to relay settings In offline mode relay disconnected to create or edit relay settings files for later transfer to relays While connected to a...

Page 138: ...captures contextual data associated with the last 1024 events listed in chronological order from most recent to oldest Oscillography The oscillography waveform traces and digital states are used to provide a visual display of power system and relay operation data captured during specific triggered events Event records are viewable at the software and device specific level Access the former under A...

Page 139: ...w areas Also any Windows Explorer directory folder is a file drag source and drop target New files that are dropped into the Offline Window are added to the tree which is automatically sorted alphabetically with respect to settings file names Files or individual menu items that are dropped in the selected device menu in the Online Window are automatically sent to the online communicating device 4 ...

Page 140: ...ER 4 INTERFACES 4 Figure 4 1 EnerVista UR Setup software window 4 1 6 Protection summary window The Protection Summary is a graphical user interface to manage elements such as enabling and disabling them Access it under Settings Protection Summary See the Settings chapter for information on use ...

Page 141: ...s installing the devices These are settings such as protection element pickup values and CT and VT ratios The settings template mode allows the user to define which settings are visible in the software Settings templates can be applied to both settings files settings file templates and online devices online settings templates The functionality is identical for both purposes Settings file conversio...

Page 142: ...s template The settings template editing feature allows the user to specify which settings are available for viewing and modification in EnerVista UR Setup By default all settings except the FlexLogic equation editor settings are locked 1 Select an installed device or a settings file from the menu on the left side of the EnerVista UR Setup window 2 Right click and select the Template Mode Edit Tem...

Page 143: ... password must be at least four characters in length 3 Enter and re enter the new password then click OK to continue The settings file template is now secured with password protection 4 1 7 4 View the settings template Once all necessary settings are specified for viewing users are able to view the settings template on the online device or settings file There are two ways to specify the settings v...

Page 144: ...itable settings The effect of applying the template to a typical settings menu is shown as follows Figure 4 7 Applying templates using the View in Template Mode settings command Use the following procedure to display settings available for editing and settings locked by the template 1 Select an installed device or a settings file from the tree menu on the left of the EnerVista UR Setup main screen...

Page 145: ...firm that you want to remove the template by clicking Yes The EnerVista software removes all template information and all settings are available 4 1 8 Secure and lock FlexLogic equations The UR allows users to secure parts or all of a FlexLogic equation preventing unauthorized viewing or modification of critical FlexLogic applications This is accomplished using the settings template feature to loc...

Page 146: ... a grey background as shown in the example Figure 4 9 Locking FlexLogic equation entries in Edit Mode 5 Click the Save button to save and apply changes to the settings template 6 Select the Template Mode View In Template Mode option to view the template 7 Apply a password to the template then click OK to secure the FlexLogic equation Once the template has been applied users are limited to view and...

Page 147: ... serial number A settings file and associated FlexLogic equations also can be locked to a UR serial number Once FlexLogic entries in a settings file have been secured use the following procedure to lock the settings file to a serial number 1 Right click the setting file in the offline window area and select the Edit Device Properties item The window opens Figure 4 12 Settings file properties windo...

Page 148: ... only included in the settings file if a complete settings file is either transferred to the L90 device or obtained from the L90 device Any partial settings transfers by way of drag and drop do not add the traceability information to the settings file Figure 4 13 Settings file traceability With respect to the figure the traceability feature is used as follows 1 The transfer date of a settings file...

Page 149: ...lable in printed settings file reports as shown in the example Figure 4 15 Settings file report showing traceability data 4 1 9 2 Online device traceability information The L90 serial number and file transfer date are available for an online device through the actual values Select the Actual Values Product Info Model Information menu item within the EnerVista online window as shown in the example ...

Page 150: ...mation is removed from the settings file If the user creates a new settings file then no traceability information is included in the settings file If the user converts an existing settings file to another revision then any existing traceability information is removed from the settings file If the user duplicates an existing settings file then any traceability information is transferred to the dupl...

Page 151: ...ons and optional user programmable pushbuttons The front panel is hinged to allow easy access to removable modules inside the chassis There is also a removable dust cover that is to be removed when accessing the keypad The standard front panel can be horizontal or vertical The following figure shows the horizontal front panel Figure 4 18 Standard horizontal front panel The following figure shows t...

Page 152: ...ed to read data such as metering actual values alarms self test messages and event records and for viewing single line diagrams Settings can be changed on the front panel except for the graphical front panel itself and for IEC 61850 The USB port connects to a computer with the EnerVista software and can be used to upgrade the relay and to transfer files and settings The USB port is the square type...

Page 153: ...es and displays Settings file conversion from previous firmware versions is supported Up to 20 characters can be used to configure some setting names in the software while up to 12 characters display on the front panel A tilde symbol is used for the twelfth character on the front panel when a name extends beyond the 12 character limit An example is shown for a Virtual Input Figure 4 21 Tilde symbo...

Page 154: ...es by page The home page displays any icons for security status active setting group active target messages and abnormal annunciator alarms present It shows the date and time of the relay If the relay synchronizes to an external time source via PTP IRIG B SNTP and so on the date time is shown in white and otherwise in yellow On pages other than the home page the header displays the name of the pag...

Page 155: ... example The Tab pushbuttons on the bottom row each navigate to their page The home page displays for a user configured time period then scrolls through user configured pages a feature referred to as rolling Holding the Home pushbutton for one second displays the product information page The Home page can also display when settings are saved for example annunciator alarm configuration using the so...

Page 156: ... 0 The following buttons display at the top of the window Save Updates the connected device if online or the open setting file if offline with any changes made in the edit session Restore Undoes any changes that have not been saved Default Changes all rolling mode settings to their factory default values Reset Displays factory default values Previous settings are not lost unless you save the reset...

Page 157: ... both open and close Tripping is unaffected unless additional logic has been configured S The position indication of the device is substituted with a manually entered value B Blocking open close command is bypassed R Autoreclose is enabled and not blocked X The device is out of service and control is not available Single line diagram example The following example outlines how to create a circuit b...

Page 158: ...s in red on the relay screen Figure 4 26 Configure Breaker and Switch settings In the EnerVista software open the single line diagram editor under Settings Product Setup Graphical Panel Single Line Diagram Editor Add the four switches for the top line by clicking the GE switch symbol in the toolbar then clicking in the window If the UR device is not online the software attempts to connect Double c...

Page 159: ...ol in the toolbar then clicking the end of the line Add three metered values by clicking the M symbol in the toolbar then clicking near the feeder arrow Double click to edit The three metered values are SRC1 Vag Mag SRC 1 P and SRC 1 Q Name the page by right clicking the bottom tab Here page 1 is renamed Milton line M568M Note that active symbols in the toolbar display and those that are inactive ...

Page 160: ...ar These two pushbuttons can be configured under Settings Product Setup User Programmable Pushbuttons Single line diagram editor use Start the application in the EnerVista software under Settings Product Setup Graphical Panel Single Line Diagram Editor The following buttons display at the top of the window Save Updates the connected device if online or the open setting file if offline with any cha...

Page 161: ...mponent s in one pixel increments when snap locations are inadequate Multiple components can be selected and moved or deleted as a group or copied and pasted to another location Right or double clicking a component opens the properties window Lines Line components represent power system buses or electrical connections between power system elements They can also be used as visual dividers and under...

Page 162: ...y the breaker or disconnect status as calculated by the element and provide means to open close tag bypass interlocking and substitute force status of the element Breaker components in addition provide means to enable disable breaker autoreclose Each breaker and each disconnect can be configured to use the UR style symbols IEC symbols or simple square slash symbols as shown in the following figure...

Page 163: ...gle line diagram Breaker and disconnect components have three different parts label symbol and flags Drag each of its parts to their final locations Double click any one of these parts in the window to open the properties window Properties that can be edited are label text breaker control element or disconnect switch element number symbol orientation horizontal or vertical color scheme red closed ...

Page 164: ...ause IEC style symbols do not use color Symbol orientation The figure shows the orientation available for the breaker and disconnect switch taking Open status as examples The default position is 0 degrees Figure 4 33 Single line diagram symbol orientation A question mark displays in a symbol on the graphical front panel when status is bad The question mark does not rotate with orientation Figure 4...

Page 165: ...CHAPTER 4 INTERFACES FRONT PANEL INTERFACE L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 4 29 4 Figure 4 35 Single line diagram static symbol orientation sheet 1 of 2 ...

Page 166: ... pushbuttons User programmable pushbuttons 1 to 8 are physical pushbuttons on the right side of the graphical front panel numbering down the two columns User programmable pushbuttons 9 to 16 can be programmed among the 10 pushbuttons on the left and right sides of the screen display They show dynamically and provide a means to perform the same control as a hardware user programmable pushbutton ...

Page 167: ...ide button 9 to pushbutton 9 in the drop down list This pushbutton then displays when appropriate on the right side of the screen display Program event record clearing Set Settings Product Setup Clear Relay Records Clear Event Records to FlexLogic operand PUSHBUTTON 9 ON Program pushbutton 9 Set Settings Product Setup User Programmable Pushbuttons Pushbutton 9 Function to Self reset Metering compo...

Page 168: ...ies that can be edited are text color and size Annunciator An annunciator is a grid of small windows for alarms actual values self test messages and product information The graphical front panel emulates a conventional annunciator panel The annunciator has 96 windows each with a description of the alarm condition that lights the window The windows are arranged in rows and columns of 3 x 4 4 x 6 or...

Page 169: ...have an active window that is on latched or unacknowledged are red Pages where alarms are not triggered have a grey Tab label Pages that have no configured windows do not have Tab pushbuttons and do not display The Up Down Left and Right pushbuttons cause the selection to move one window in the indicated direction Pressing the Right pushbutton past the last window in a row scrolls the display to a...

Page 170: ...d for transient signals such as trip and it conforms to ISA 18 1 1979 R2004 standard type M 6 Figure 4 41 Annunciator alarm sequence in Latched mode In Acknowledgeable mode both Off to On and On to Off state changes in the configured operand cause the background to flash the window must be acknowledged reset to cancel flashing This mode conforms to ISA 18 1 1979 R2004 standard type R 6 ...

Page 171: ...ETTINGS INPUTS OUTPUTS RESETTING RESET ANNUNCIATOR setting can be used to select a FlexLogic operand that when activated acknowledges resets all annunciator windows Annunciator editor The annunciator editor is used to configure alarms and actual value displays for the graphical front panel The path in the EnerVista software is Settings Product Setup Graphical Panel Annunciator Editor The figure sh...

Page 172: ...file if offline with any changes made in the edit session on any page Restore Undoes any changes that have not been saved Default Changes all annunciator settings on all pages to their factory default values Reset Displays factory default values Previous settings are not lost unless you save the reset window Metering editor The metering editor is an actual values editor It creates pages of actual ...

Page 173: ...ame of table or column heading If the metering input setting is other than OFF the value of the selected metering input displays formatted according to the size text color units multiplier and decimal configuration Otherwise either the Text or the Off Text displays depending on the value of the operand selected by setting Status Input Index A maximum of eight Status Inputs Indexes can be used per ...

Page 174: ... the feature select a CONDITION select its ACTIVATE PAGE option then save When selecting an operand open the drop down list and start typing in the field to auto fill For example typing F displays FIRST ETHERNET FAIL The following buttons display at the top of the window Save Updates the connected device if online or the open setting file if offline with any changes made in the edit session on the...

Page 175: ...tton closes the setting without saving If a popup menu is open this pushbutton closes it If an item is selected this pushbutton deselects it Otherwise this pushbutton activates the previous page in the page hierarchy RESET Clears all latched LED indications and target messages When a page with acknowledgeable resettable items is displayed it instead resets acknowledges all items on that page or if...

Page 176: ...formation see the Test Mode section in the Settings chapter TRIP Indicates that the FlexLogic operand serving as a trip switch has operated This indicator always latches initiate the reset command to reset the latch ALARM Indicates that the FlexLogic operand serving as an alarm switch has operated This indicator never latches PICKUP Indicates that an element is picked up This indicator never latch...

Page 177: ...ation of these LEDs is user defined Support for applying a customized label beside every LED is provided Default labels are shipped in the label package of every L90 together with custom templates The default labels can be replaced by user printed labels User customization of LED operation is of maximum benefit in installations where languages other than English are used to communicate with operat...

Page 178: ...rand is reset All elements that are able to discriminate faulted phases can independently turn off or on the phase A B or C LEDs This includes phase instantaneous overcurrent phase undervoltage and so on This means that the phase A B and C operate operands for individual protection elements are ORed to turn on or off the phase A B or C LEDs VOLTAGE Indicates voltage was involved CURRENT Indicates ...

Page 179: ...nd LEDs 6 to 14 are programmable Status indicators IN SERVICE Indicates that control power is applied all monitored inputs outputs and internal systems are fine the relay s test mode is disabled and the relay is in online Programmed mode under Settings Product Setup Installation TROUBLE Indicates that the relay has detected an internal problem Check the self test messages outlined at the end of th...

Page 180: ... operand The labelling area has a clear cover behind which custom labels can be mounted A utility is available to print stick on labels as outlined later in this chapter These LEDs are programmed by default as follows PICKUP LED 6 Indicates that an element is picked up and hence a trip can be imminent VOLTAGE LED 7 Indicates voltage was involved CURRENT LED 8 Indicates current was involved FREQUEN...

Page 181: ...buttons to customize 5 Feed the UR front panel label cutout sheet into a printer and press the Print button in the front panel report window 6 When printing is complete fold the sheet along the perforated lines and punch out the labels 7 Remove the UR label insert tool from the package and bend the tabs as described in the following procedures These tabs are used for removal of the default and cus...

Page 182: ...emoval tool 1 Bend the tabs at the left end of the tool upwards as shown Bend the tab at the center of the tool tail as shown To remove the LED labels from the L90 front panel and insert the custom labels 1 Use the knife to lift the LED label and slide the label tool underneath Ensure that the bent tabs are pointing away from the relay ...

Page 183: ...bel tool to the LED label 3 Remove the tool and attached LED label as shown 4 Slide the new LED label inside the pocket until the text is properly aligned with the LEDs as shown To remove the user programmable pushbutton labels from the L90 front panel and insert the custom labels 1 Use the knife to lift the pushbutton label and slide the tail of the label tool underneath as shown Ensure that the ...

Page 184: ...e the label tool under the user programmable pushbutton label until the tabs snap out as shown This attaches the label tool to the user programmable pushbutton label 3 Remove the tool and attached user programmable pushbutton label 4 Slide the new user programmable pushbutton label inside the pocket until the text is properly aligned with the ...

Page 185: ...he EnerVista software if the L90 is not already listed in the Offline Window area add it by right clicking it and selecting the Add Device to Offline Window option 2 Click the File Front Panel Report menu item and select the device 3 In the Front Panel Report window double click an LED or pushbutton slot and type a label If you need to see the existing front panel remotely access Actual Values Fro...

Page 186: ... labels are on the top left of the template sheet and the blank labels are on the bottom right Use the pre printed labels or use the designer provided in the software and print the labels onto the template One sheet is provided The example shows LED labeling in the top right portion and pushbutton labeling in the bottom right portion To create LED and pushbutton labels for the front panel 1 In the...

Page 187: ...splays so any labels deleted are not lost 4 2 6 Menu navigation Press the MENU key to display selections or home page Each press of the key advances through the following main headings Actual Values Settings Commands Targets Factory Service User displays when enabled 4 2 6 1 Enhanced and standard front panels The setting and actual value pages are arranged hierarchically Header display pages are i...

Page 188: ...s displayed depend on order code Highest level Lowest level setting value SETTINGS PRODUCT SETUP SECURITY ACCESS LEVEL Restricted SETTINGS SYSTEM SETUP ACTUAL VALUES STATUS Press the MENU key until the Actual Values header page appears This page contains system and relay status information SETTINGS PRODUCT SETUP Press the MENU key until the Settings header page appears This category contains setti...

Page 189: ... allows the setting selection to continue upward from the minimum value The VALUE down arrow decrements the displayed value by the step value down to the minimum value While at the minimum value pressing the VALUE down arrow again allows the setting selection to continue downward from the maximum value FLASH MESSAGE TIME 10 0 s For example select the SETTINGS PRODUCT SETUP DISPLAY PROPERTIES FLASH...

Page 190: ...w context sensitive help Flash messages appear sequentially for several seconds each For the case of a text setting message pressing HELP displays how to edit and store new values 4 2 7 2 Graphical front panel When enabling an element in the EnerVista software that outputs to an actual value the actual values menu is not updated on the graphical front panel via Ethernet connection when the actual ...

Page 191: ...URRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 4 55 4 Figure 4 56 Main menu Use the Up or Down pushbutton to select SETTINGS then press the Right or ENTER pushbutton Figure 4 57 Settings menu With PRODUCT SETUP selected press the Right or ENTER pushbutton ...

Page 192: ...e 4 59 Display Properties menu Use the Up or Down pushbutton to select FLASH MESSAGE TIME then press the Right or ENTER pushbutton If the relay is configured to require login to edit settings and the user is not already logged in the login page displays When the user has successfully logged in the setting is opened for edit As the FLASH MESSAGE TIME setting accepts a numerical value a keypad displ...

Page 193: ...e decimal point selected enters that character at the insertion point Push ENTER now to accept the 4 Press the Save Tab pushbutton which does a range check on the value saves the setting when valid closes the page and displays the previous page When a setting is not saved due to an invalid value a message flashes for example being out of range In cases where the relay needs to be restarted for set...

Page 194: ...nd columns Each cell can include either configurable static text or the value of a selected FlexLogic operand FlexAnalog operand or actual value The font size background and foreground color and actual value formatting are configurable independently in each cell as is the number of rows and number of columns on each page To display a metering page press the Home pushbutton then the Metering Tab pu...

Page 195: ...es the application monitors the state of the breaker that can be presented on front panel LEDs along with a breaker trouble indication Breaker operations can be manually initiated from the front panel keypad or automatically initiated from a FlexLogic operand A setting is provided to assign names to each breaker this user assigned name is for the display of related flash messages These features ar...

Page 196: ... breakers 4 2 10 Change passwords The information in this section refers to password security For information on how to set the password for the first time or change CyberSentry passwords see the previous chapter or the Settings Product Setup Security CyberSentry section in the next chapter ENTER COMMAND PASSWORD This message appears when the USER 1 USER 2 or USER 3 key is pressed and a COMMAND PA...

Page 197: ...hanges to any of the setting values Changing any setting Test mode operation Command Restricts the user from making any settings changes but allows the user to perform the following operations Operating the breakers via front panel keypad Changing the state of virtual inputs Clearing the event records Clearing the oscillography records Clearing fault reports Changing the date and time Clearing the...

Page 198: ...the right side which are products of the manipulations with inputs logical gates and logical operators to produce new operands and define the output state of the element True and false values are denoted by 1 and 0 respectively A function usually is high on enabled when 1 Reading from right to left in the following diagram the TRIP BUS 1 OP and TRIP BUS 1 PKP FlexLogic operands on the right side a...

Page 199: ...ng FlexLogic Drag and drop interface Open multiple tabs and edit simultaneously Display symbols in IEC ISO or UR formats Export a diagram as BMP file or copy it to the clipboard for import into other applications Scale and print files in various paper sizes Works with all UR firmware versions The figure shows an example where several inputs are used to trigger an output With the OR function any on...

Page 200: ...iagram in the Offline Window area of the EnerVista UR Setup software Compile it and troubleshoot any errors The logic populates automatically into the FlexLogic Equation Editor Upload the file to the live device Monitor the output This section explains how to use Engineer It outlines the following topics Design logic Send file to and from device Monitor logic View front panel Generate connectivity...

Page 201: ...eets Optimize the logic Change logic order Search logic Exclude sheet from compile 4 4 1 1 Examples Create oscillography trigger every three minutes Figure 4 66 Three minute timer turns on LED for 10 seconds Preparation Under Settings Inputs Outputs Virtual Outputs the first and second virtual outputs are named OscTrigger Top logic Three minute timer trigger Bottom logic Turn on LED 1 for 10 secon...

Page 202: ...n the Online Window area and select the Add Device to Offline Window option Upon saving the modified FlexLogic a yellow icon appears for the device in the Offline Window area to indicate that the logic differs from the Online device 2 In the Offline Window area access Engineer for the device then Logic Designer The logic opens 3 Click the Edit Auto Populate Workbook menu item If the software promp...

Page 203: ...grammable LEDs circles Figure 4 70 Default view of FlexLogic designer 2 Optionally delete the default logic diagram by right clicking its tab at the bottom of the window and selecting Delete 3 To add a blank sheet click Edit Add Sheet A new tab displays Or use the last tab displayed which is a blank sheet 4 Optionally right click the new tab and Rename it 5 Add the input blocks to the logic diagra...

Page 204: ... the logic sheet to add it Double click the block on the sheet to configure it For the name make it unique The figure shows virtual output 61 is being added with a suffix of io added to the name to make it unique Note that the outline color of a block is red until it is configured and that this properties window varies by block and the selectable options by order code Figure 4 72 Configuring an ou...

Page 205: ...iguring them 11 Compile the logic diagram to check for errors by clicking the Compile button at the bottom left or by pressing the F7 key If prompted about a message about sorting click Yes to apply the default for this example which can be automatic sorting based on an algorithm that applies fastest execution time With successful compiling the file is saved and the FlexLogic equations populate au...

Page 206: ...4 1 4 Compiled results and warning messages When a yellow caution icon displays in the Offline Window area it means that the settings file is not synchronized with the online device Right click the device in the Offline Window area and select the Update SCL files option SCL refers to the Substation Configuration Language An Instantiated IED capability description IID file is an example of an SCL f...

Page 207: ...ple seven of 512 available Virtual Output equations The number of FlexLogic equations used in the Logic Designer window Timers used The number of timers used in the Logic Designer window Memory Used The percent of memory used in the Logic Designer window Errors Table 4 3 Errors from compiling Category Blockorgate affected Message Description Error All Number of lines nnn exceeds maximum limit of 5...

Page 208: ...version Possible cause The order code and or version of the settings file was converted causing the input parameter to become unavailable Category Block or gate affected Message Description Minor warning Input Input set to unused VO SYMBOL_ID Name Sheet An Input symbol is using an unassigned Virtual Output Major warning Tag Out Tag out not connected TAG_ID Sheet A Tag Out symbol has no input Major...

Page 209: ...ement to the sheet where the first sheet is to connect 5 Double click the element and in the window that opens select the first sheet from the drop down list to connect the two sheets 6 Save the work 4 4 1 7 Optimize the logic The number of available FlexLogic entries depends on firmware for example 515 or 1024 lines The software can automatically optimize a logic diagram to reduce space and free ...

Page 210: ...resh button 3 Select an entry and click the up or down arrow To cancel any manual changes click the Sort or Refresh button 4 Recompile The change is not executed or saved if automatic sorting is enabled Figure 4 82 Ordering FlexLogic entries To set automatic sorting 1 In Engineer under File Preferences select the Compiler option The Automatically Sort VOs option means that the block with the faste...

Page 211: ...lar to Sheet 1 Figure 4 84 Excluding a tab from compiling Figure 4 85 Tab excluded from compiling 4 4 2 Send file to and from device With the logic diagram created compiled and errors eliminated the FlexLogic can be sent to a live device And conversely a file from a live device can be added to the Offline Window area for additional work To send a file to a device 1 In the Offline Window area of th...

Page 212: ...s the settings file To view results 1 In the Offline Window area of the software expand the Engineer entry for the device 2 Double click the Logic Designer entry and Compile the logic 3 Double click the Logic Monitor entry or click the M button in the toolbar at the top of the window With successful launch the logic displays and a green indicator displays at the bottom of the tab When the file is ...

Page 213: ... of the software expand the Engineer entry for the device 2 Double click the Front Panel Report entry The report displays The Device Summary is read from the settings file and cannot be changed The LEDs and pushbuttons display below the summary 3 To save the report click File Save As enter a file name and select the front panel report FPR JPG or PDF format Figure 4 87 Front panel display in Engine...

Page 214: ...try for the device 2 Double click the Device Connectivity Report entry The report displays 3 To save as a PDF file click File Save As Figure 4 88 Device Connectivity Report 4 4 6 Preferences Preferences determine functionality As such you are encouraged to review them This section outlines some options available in the menus and preference panels Access them in the Logic Designer panel under the V...

Page 215: ...mation in the File Information panel Show Sheet Name When enabled shows Sheet 1 Sheet 2 or any other name at the top of the logic diagram when printing Start Sheet On New Page Places the sheet on the next page when printing Show Notes Selection When other than None prints the text from any information notes added to the document under Drawing Tools tab Note The text is printed after the logic diag...

Page 216: ...en you next open the Logic Designer window The settings apply to all products not just the active window when it is next opened Close then reopen the Logic Designer window for the setting to take effect Compiler Show Warnings Options to filter the messages that display when logic compiles Minor Enable to display minor errors An example is using the default values of an element added to the diagram...

Page 217: ...rite timing information in a spreadsheet The timing information is recorded in a text file that uses commas to separate each of the fields This file uses the extension CSV that is supported by any spreadsheet application Every change written to the CSV file requires a timestamp The format for the timing information in the output window is as follows yyyy mm dd hh dd ss devicename offline yyyy mm d...

Page 218: ...r of the Virtual Output list to the right of the icon Virtual Outputs can be sorted numerically in ascending and descending order based on numbers and names Select VO to View x x Select a Virtual Output to locate and select it in the workbook Each Virtual Output listed also contains the name of the sheet where the Virtual Output is located Edit Mode Logic Designer Switch to Logic Designer mode Mon...

Page 219: ...ck for each line Double click to finish Draw oval or circle Click and drag to draw Add text box with rectangle around it Click to add Double click it to change text Add figure Select file in the window that opens then click on diagram canvas to add figure Add note icon and text Click to add Double click to edit the title and text Input symbol that can be configured to any FlexLogic operand value R...

Page 220: ...d register called a virtual output Virtual outputs can be used as an input operand in any equation including the equation that generates the output as a seal in or other type of feedback Place and configure a Remote Output The UR s order code and firmware version then determine the availability of the Remote Output Place and configure a Direct Output The UR s order code and firmware version then d...

Page 221: ...erands have a value of one and otherwise gives a value of one It gives an output signal until all signals are present on its inputs An inverter that reverses the logic state The number of inputs is configurable from two to 16 Place a XOR gate in the Logic Designer diagram which is two exclusive OR gates Only one action needs to occur If there are two inputs or there is no input there is no output ...

Page 222: ...TRL key to select others Or click and drag an area that contains multiple components to select Edit Vertices Shows vertices points for the component selected if the component support vertices manipulation Properties Shows the properties of the selected component Zoom Normal Zoom in and center the screen to the spot selected Zoom to Fit Zoom in to a magnitude that fits your entire schema layout on ...

Page 223: ...left right Rotate Rotates selected component freely Once selected put your mouse cursor over the component and move the component clockwise or counter clockwise depending on what you need Rotate Left Right Rotates selected component 90 degrees counter clockwise or clockwise Flip Vertical Flips the selected component on the vertical axis Flip Horizontal Flips the selected component on the horizonta...

Page 224: ...4 88 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL FLEXLOGIC DESIGN USING ENGINEER CHAPTER 4 INTERFACES 4 ...

Page 225: ... the relay accessing the Device Information Menu option then the Front Panel Display Report option When indicated that a restart is required for a setting change to take effect use the Maintenance Reboot Relay Command in the software 5 1 Settings menu SETTINGS PRODUCT SETUP SECURITY See page 5 8 DISPLAY PROPERTIES See page 5 27 GRAPHICAL FRONT PANEL Access in EnerVista See page 5 29 CLEAR RELAY RE...

Page 226: ...ION See page 5 135 REMOTE RESOURCES Access in EnerVista See page 5 136 SETTINGS SYSTEM SETUP AC INPUTS See page 5 137 POWER SYSTEM See page 5 138 SIGNAL SOURCES See page 5 139 87L POWER SYSTEM See page 5 142 BREAKERS See page 5 150 SWITCHES See page 5 155 FLEXCURVES See page 5 160 PHASOR MEASUREMENT UNIT See page 5 167 SETTINGS FLEXLOGIC FLEXLOGIC EQUATION EDITOR See page 5 209 FLEXLOGIC TIMERS Se...

Page 227: ...NCY See page 5 341 SYNCHROCHECK See page 5 342 DIGITAL ELEMENTS See page 5 347 DIGITAL COUNTERS See page 5 350 MONITORING ELEMENTS See page 5 352 PILOT SCHEMES See page 5 376 AUTORECLOSE See page 5 399 FREQUENCY RATE OF CHANGE See page 5 412 SETTINGS INPUTS OUTPUTS CONTACT INPUTS See page 5 413 VIRTUAL INPUTS See page 5 415 CONTACT OUTPUTS See page 5 416 VIRTUAL OUTPUTS See page 5 420 DIRECT INPUT...

Page 228: ...f an element are shown on a logic diagram This includes the inputs settings fixed logic and the output operands generated The previous chapter explains how to read a logic diagram and the abbreviations used in a diagram are defined in the Abbreviations chapter Some settings are specified in per unit pu calculated quantities pu quantity actual quantity base quantity Where the current source is from...

Page 229: ...rate output states RESET DELAY setting This setting is used to set a time delay on dropout or off delay for the duration between the operate output state and the return to logic 0 after the input transits outside the defined pickup range BLOCK setting The default output operand state of all comparators is a logic 0 or flag not set The comparator remains in this default state until a logic 1 is ass...

Page 230: ...ocess by selecting the instrument transformer input channels to use and some parameters calculated from these channels The input parameters available include the summation of currents from multiple input channels For the summed currents of phase 3I_0 and ground current current from CTs with different ratios are adjusted to a single ratio before summation A mechanism called a source configures the ...

Page 231: ...low the provision of additional features that operate on the individual currents such as breaker failure Given the flexibility of this approach it becomes necessary to add configuration settings to the platform to allow the user to select which sets of CT inputs are added to form the net current into the protected device The internal grouping of current and voltage signals forms an internal source...

Page 232: ...input channel configuration Upon relay startup configuration settings for every bank of current or voltage input channels in the relay are generated automatically from the order code Within each bank a channel identification label is assigned automatically to each bank of channels in a given product The bank naming convention is based on the physical location of the channels required by the user t...

Page 233: ...st be 8 to 20 characters in length Password must contain characters from all of the following categories English uppercase characters A through Z English lowercase characters a through z Base 10 digits 0 through 9 Non alphabetic characters for example 5 3 1 2 Password security SETTINGS PRODUCT SETUP SECURITY The L90 supports password entry from a local or remote connection Local access is defined ...

Page 234: ...ront panel display and are disabled either by the user or by timeout via the setting and command level access timeout settings The remote setting and command sessions are initiated by the user through the EnerVista software and are disabled either by the user or by timeout The state of the session local or remote setting or command determines the state of the following FlexLogic operands ACCESS LO...

Page 235: ...o the access level timeout setting values and when power is cycled Change remote passwords Proper passwords are required to enable each command or setting level access which are explained in the previous section SETTINGS PRODUCT SETUP SECURITY CHANGE REMOTE PASSWORDS To set the command or setting password in EnerVista 1 In the EnerVista software or from the front panel navigate to Settings Product...

Page 236: ...an be programmed to raise an alarm via contact outputs or communications This feature can be used to protect against both unauthorized and accidental access attempts The UNAUTHORIZED ACCESS operand is reset with the COMMANDS CLEAR RECORDS RESET UNAUTHORIZED ALARMS command Therefore to apply this feature with security password protect the Command level The operand does not generate events or target...

Page 237: ... ACCESS message displays on the front panel If this setting is Off firmware upgrades are blocked If this setting is On firmware upgrades are allowed REMOTE SETTING AUTH This setting is used for remote Ethernet or RS485 interface setting access supervision If this setting is On the default setting then remote setting access functions as normal that is a remote password is required If this setting i...

Page 238: ...ting represents the timeout delay remote setting access It applies when the Remote Settings Authorized setting is programmed to any operand except On or Off The state of the FlexLogic operand is continuously monitored for an off to on transition When this occurs remote setting access is permitted and the timer programmed with the Access Authorized Timeout setting value is started When this timer e...

Page 239: ...ing pre requisites are required to add user accounts to the EnerVista security management system The user adding the account must have administrator rights The EnerVista security management system must be enabled previous section To add a user account 1 Select the Security User Management item from the top menu to open the user management window 2 Enter a username in the User field The username mu...

Page 240: ...d Description Delete Entry Deletes the user account when exiting the user management window Actual Values Allows the user to read Actual Values Settings Allows the user to read Settings values Commands Allows the user to execute Commands Event Recorder Allows the user to use the Event Recorder FlexLogic Allows the user to read FlexLogic values Update Info Allows the user to write to any function t...

Page 241: ...values Settings Allows the user to read setting values Commands Allows the user to execute commands Event Recorder Allows the user to use the digital fault recorder FlexLogic Allows the user to read FlexLogic values Update Info Allows the user to write to any function to which they have read privileges When any of the Settings Event Recorder and FlexLogic check boxes are enabled by themselves the ...

Page 242: ...formation is displayed in plain text by the EnerVista software or the UR device nor are they ever transmitted without cryptographic protection When CyberSentry is enabled Modbus communications over Ethernet is encrypted which is not always tolerated by SCADA systems The UR has a bypass access feature for such situations which allows unencrypted Modbus over Ethernet The Bypass Access setting is ava...

Page 243: ...YSTEM INSTRUCTION MANUAL 5 19 5 Figure 5 3 Security panel when CyberSentry installed For the Device Settings Product Setup Supervisory option the panel looks like the following Figure 5 4 Supervisory panel For the Security panel the following settings are available ...

Page 244: ...sts 0 9999 10 sec Administrator Retries Number of retries before giving up 0 9999 3 Administrator Confirm RADIUS Authentication Shared Secret Confirmation of the shared secret The entry displays as asterisks See the Password Requirements section 245 characters N A Administrator Setting name Description Minimum Maximum Default Units Minimum permission Session Lockout Number of failed authentication...

Page 245: ...S server documents See RADIUS server document s Administrator Password Local device roles except for Observer are password protected All RADIUS users are password protected See the Password Requirements section earlier in this chapter See the following password section for requireme nts Change Me1 Text The specified role and Administrator except for Supervisor where it is only itself Setting name ...

Page 246: ...e fact Only a Supervisor can set the Settings Lock and Firmware Lock in the Security settings This role also has the ability to forcefully log off any other role and clear the security event log This role can also be disabled but only through a Supervisor authentication When this role is disabled its permissions are assigned to the Administrator role Observer This role has read only access to all ...

Page 247: ...able for Supervisor role only or if the Supervisor role is disabled then for the Administrator role only In Device authentication mode the Observer role does not have a password associated with it In Server authentication mode the Observer role requires a password If you are locked out of the software contact GE Grid Solutions for the default password When using CyberSentry the default password is...

Page 248: ...anges or firmware upgrade After all the setting changes are applied or commands executed the Supervisor enables to lock settings changes Example If this setting is enabled and an attempt is made to change settings or upgrade the firmware the UR device denies the settings changes or denies upgrading the firmware If this setting is disabled the UR device accepts settings changes and firmware upgrade...

Page 249: ...ADIUS server itself also must be configured The appendix called RADIUS Server at the end of this instruction manual gives an example of how to set up a simple RADIUS server Once both the RADIUS server and the parameters for connecting the UR to the server have been configured you can choose Server authentication on the login screen of EnerVista To configure Server authentication 1 In the EnerVista...

Page 250: ...umber index Date Timestamp UTC date and time Username 255 chars maximum but in the security log it is truncated to 20 characters IP address Device IP address Role 16 bit unsigned of type format F617 Activity Value 16 bit unsigned If System Integrity Recovery events are logged during a restart of the unit due to an incorrect shutdown sequence upgrade the firmware to version 7 31 or later to correct...

Page 251: ..._LOCK ORIGIN TIMESTAMP Critical 1 An attempt was made to change firmware while the firmware lock was enabled SETTING_CHG ORIGIN TIMESTAMP Notice 5 Indicates setting change s SETTING_LOCK ORIGIN TIMESTAMP Critical 1 An attempt was made to change settings while the settings lock was enabled LOGIN ORIGIN TIMESTAMP Warning 4 Indicates when a certain role logged in LOGOUT ORIGIN TIMESTAMP Notice 5 Indi...

Page 252: ...hese settings are not supported on the graphical front panel CURRENT CUT OFF LEVEL This setting modifies the current cut off threshold Very low currents 1 to 2 of the rated value are very susceptible to noise Some customers prefer very low currents to display as zero while others prefer the current to display even when the value reflects noise rather than the actual signal The L90 applies a cut of...

Page 253: ...ical front panel The settings are not accessible from the graphical front panel The following screens are available Home page Rolling mode Metering editor Single line diagram editor Annunciator editor Configurable navigation The settings menu and the event record pages are not configurable 5 3 3 1 Home page This page sets the display on the home page and the date and time formats for all pages Opt...

Page 254: ...n without a page number specifies the first annunciator page in the following sequence The first annunciator page that contains an annunciator window that is in alarm fast flash The first annunciator page that contains an annunciator window that is in ringback Ringback is a return alert Visual and audible signals are given when conditions return to normal then the sequence returns to normal by pus...

Page 255: ... and the Time Format use the defaults the date and time are separated by the character T per the ISO convention Otherwise they are separated by a space If the relay is synchronized to an external time source via PTP IRIG B SNTP and so on the date time is shown in white and otherwise in yellow hh two digit hour for example 02 for two o clock h one or two digit hour for example 2 for two o clock mm ...

Page 256: ...es rolling mode and displays the annunciator page containing the changed state Screen Saver Delay Range 0 to 900 s in steps of 1 Default 300 s The screen saver mode extends the life of the display After the amount of time set here the screen saver activates and the display intensity is reduced to the level set by the Screen Saver Intensity setting When in rolling mode rolling continues while the s...

Page 257: ...evaluated which can result in the display of a different annunciator page in the rolling sequence The Tabular option displays a configured actual values metering page The Targets option displays error messages 5 3 3 3 Metering editor This feature creates tables of actual metered values for the graphical front panel It configures the content that displays in the Metering Tab pushbutton An actual va...

Page 258: ... operand Default OFF This setting identifies the potential inputs for use in the STATUS INDEX fields for display of the status of FlexLogic operands A maximum of eight Status Inputs can be used per metering page and 16 in all metering pages Select the metering input from the drop down list The options reflect the FlexLogic operands applicable to the L90 They are inputs for all five metering pages ...

Page 259: ...s to display instead of a metered value A maximum of eight Status Inputs can be used per metering page and 16 in all metering pages STATUS INDEX Range 1 16 Default This field becomes active when the CONTENT field is set to Status It selects the input from the STATUS INPUTS to display the on off status of the selected operand TEXT Range up to 20 alphanumeric characters Default Enter the text to dis...

Page 260: ...ected The field can be left blank when units of measure do not apply for example with RxGOOSE Analogs Scale Factor Range G Giga M Mega k Kilo None Default None This setting allows the user to specify the scaling factor for the metering units value Options depend on the Parameter Multiplier Range 1000000 to 1000000 Default 1 0 This setting allows the user to specify a multiplier for the metering pa...

Page 261: ...ext and color then save On the graphical front panel view the alarm by pressing the Annunciator Tab pushbutton at the bottom of the Home page Alarms do not display automatically Acknowledge or reset the alarm by navigating to it with the arrow pushbuttons then press the ENTER or RESET pushbutton The figure shows alarms for basic functions The last annunciator page is named Device Alarms Alarms are...

Page 262: ...ame as the one defined in Settings Inputs Outputs Resetting Reset Annunciator see the Resetting section in this chapter LAYOUT Range 3x4 4x6 6x8 Default 3x4 Selects the number of rows and columns to display on the annunciator pages For example 3x4 means 12 windows display per page over eight pages Up to 96 entries are possible To view the layout click the Preview button PAGE NAMES Range up to 20 a...

Page 263: ...sitions as outlined in the Annunciator section of the Interfaces chapter Self Reset Track the state of the input operand The alarm turns on when the trigger activates and off when the trigger clears Latched Alarm remains latched and can be reset using the RESET button To acknowledge reset unlatch an alarm use the arrow buttons on the graphical front panel and press the Enter button TEXT LINE 1 to ...

Page 264: ...alue Display in Line Range 1 2 3 Default 1 This setting specifies the line in the annunciator alarm window to display the metered value A specified actual value replaces the text for the selected line For example 2 means the value displays in line 2 of the text Any text configured to display in that line does not display 5 3 3 6 Configurable navigation The path is Settings Product Setup Graphical ...

Page 265: ...ies the page to display on the graphical front panel when the FlexLogic operand selected by its CONDITON setting transitions from Off to On The Annunciator option without a page number specifies the first annunciator page in the following sequence The first annunciator page that contains an annunciator window that is in alarm fast flash The first annunciator page that contains an annunciator windo...

Page 266: ...on 1 to clear demand records apply the following settings 1 Assign the clear demand function to pushbutton 1 by making the following change in the SETTINGS PRODUCT SETUP CLEAR RELAY RECORDS menu CLEAR DEMAND PUSHBUTTON 1 ON 2 Set the properties for user programmable pushbutton 1 by making the following changes in the SETTINGS PRODUCT SETUP USER PROGRAMMABLE PUSHBUTTONS USER PUSHBUTTON 1 menu PUSHB...

Page 267: ...after receiving data from a host This feature allows operation with hosts that hold the RS485 transmitter active for some time after each transmission 5 3 5 3 Ethernet network topology The L90 has three Ethernet ports Each Ethernet port must belong to a different network or subnetwork Configure the IP address and subnet to ensure that each port meets this requirement Two subnets are different when...

Page 268: ... x x x Single LAN no redundancy The topology shown in the following figure allows communications to SCADA local configuration monitoring through EnerVista and access to the public network shared on the same LAN No redundancy is provided Figure 5 13 Network configuration for single LAN Multiple LANS with redundancy The following topology provides local configuration monitoring through EnerVista sof...

Page 269: ...ANS no redundancy The following topology provides local configuration monitoring through EnerVista software on LAN1 to which port 1 P1 is connected access to the public network on LAN2 to which port 2 P2 is connected and communications with SCADA on LAN3 to which port 3 P3 is connected There is no redundancy Figure 5 15 Multiple LANS no redundancy ...

Page 270: ...t 2 MAC address IP address and mask PRT1 2 or 3 IP ADDRESS This setting sets the port s IPv4 address in standard IPV4 format This setting is valid on port 3 if port 2 REDUNDANCY is set to None PRT1 2 or 3 SUBNET MASK This setting sets the port s IPv4 subnet mask in standard IPV4 format This setting is valid on port 3 if port 2 REDUNDANCY is set to None PRT1 2 or 3 FUNCTION This setting enable disa...

Page 271: ...tter connectivity is used Behavior for GOOSE messages is as follows If REDUNDANCY is set to Failover or PRP In order to transmit a GOOSE message on port 2 the CID file must be configured to have the corresponding GSE element in both ConnectedAPs S2 and S3 In the EnerVista software the TxGOOSE PORT ASSIGNMENT needs to be Ports 1 2 3 to transmit GOOSE on both ports 1 and 2 or Ports 2 3 to have GOOSE...

Page 272: ...module called a Link Redundancy Entity LRE LRE is responsible for duplicating frames and adding the specific PRP trailer when sending the frames out on the LAN as well as making decisions on received frames as to which one is sent up the OSI stack to the application layer and which one is discarded LRE is responsible for making PRP transparent to the higher layers of the stack In addition there is...

Page 273: ...route entries numbered 1 to 6 to configure a static network route Once a route destination is configured for any of the entries 1 to 6 that entry becomes a static route and it must meet all the rules listed in the next section General Conditions to be Satisfied by Static Routes 2 To configure the default route enter a default gateway address Once a default gateway address is configured it must be ...

Page 274: ...eases Prior to release 7 10 UR devices did not have an explicit manner of configuring routes The only available route was the default route configured as part of the network settings port gateway IP address This limited the ability to route to specific destinations particularly if these destinations were reachable through a different interface than the one on which the default gateway was Starting...

Page 275: ... uses a different gateway 10 1 2 1 than the default route This gateway is the address of Router2 which has knowledge about 10 1 3 0 and is able to route packets coming from the UR and destined to EnerVista Show routes and ARP tables This feature is available on the Web interface where the main menu contains an additional Communications menu and two submenus Routing Table ARP Table The tables outli...

Page 276: ...UMBER is set to any other port The MODBUS TCP PORT NUMBER setting sets the TCP port used by Modbus on Ethernet A MODBUS TCP PORT NUMBER of 0 disables Modbus over TCP IP meaning closes the Modbus TCP port When the port number is changed to 0 the change takes effect when the L90 is restarted When it is set to 0 use the front panel or serial port to communicate with the relay 5 3 5 9 Protocol selecti...

Page 277: ...hannel 2 RS232 DNP Modbus DNP Modbus IEC 61850 Channel 1 RS485 Channel 2 Eth TCP Modbus DNP DNP Modbus IEC 61850 Channel 1 RS232 Channel 2 Eth TCP DNP Modbus DNP Modbus IEC 61850 Channel 1 RS485 Channel 2 RS232 DNP DNP Modbus IEC 61850 Channel 1 RS232 Channel 2 RS485 DNP DNP Modbus IEC 61850 Channel 1 RS485 Channel 2 none Modbus DNP Modbus IEC 61850 IEC 104 Modbus Modbus IEC 104 Modbus IEC 61850 I...

Page 278: ... DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 DNP ENERGY DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 DNP PF DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 DNP OTHER DEFAULT DEADBAND 30000 Range 0 to 100000000 in steps of 1 DNP TIME SYNC IIN PERIOD 1440 min Range 1 to 10080 min in steps of 1 DNP MESSAGE FRAGMENT SIZE 240 Range 30 to 2048 in steps of 1 DNP OBJEC...

Page 279: ...ts When this value is set to Network UDP the DNP protocol can be used over UDP IP on channel 1 only The Front Panel RS232 setting does not apply to the graphical front panel when selected the DNP client cannot establish a connection on a USB port For any change to take effect restart the relay The DNP ADDRESS setting is the DNP slave address This number identifies the L90 on a DNP communications l...

Page 280: ...RIATION settings select the DNP default variation number for object types 1 2 20 21 22 23 30 and 32 The default variation refers to the variation response when variation 0 is requested and or in class 0 1 2 or 3 scans See the DNP Implementation section in the UR Family Communications Guide The DNP binary outputs typically map one to one to IED data points That is each DNP binary output controls a ...

Page 281: ...ettings are not accessible from the front panel of the device Overview IEC 61850 is a series of international standards and technical reports applicable to power utility automation systems It includes semantics abstract communication services specific communication services performance specifications network engineering guidelines configuration description methodologies and engineering processes T...

Page 282: ...concerned with the IEC 61850 protocol can nevertheless be accessed via IEC 61850 These settings are documented elsewhere in this Settings chapter This section of the Settings chapter deals solely with the settings that configure the IEC 61850 protocol itself The maximum number of simultaneous clients supported by the UR family is five EnerVista setup for IEC 61850 The EnerVista UR Setup software p...

Page 283: ...this when applicable Panels for other devices can be open concurrently to facilitate parameter coordination When CyberSentry security is enabled editable settings depend on the user role logged in For example an Administrator and Engineer can change settings If prompted for a Settings password it means the Administrator or Engineer password The Restore button restores settings in the window to the...

Page 284: ... panels and clicking Developer IID CID Viewer in the software a CID file generates and an SCL Viewer shows the updated CID file content There are no edit or save functions use instead the Back Up and Restore Settings instructions later in this document to save the files Searches are case insensitive Figure 5 20 View CID settings file Server configuration The Server Configuration panel contains IEC...

Page 285: ...ing characters Default This setting sets the LN Prefix of the FlexLogic operand interface logical node GGIO1 that is described in the GGIO1 section later Valid characters are upper and lowercase letters digits and the underscore _ character The first character must be a letter UR Setup software does not allow entry of a prefix that duplicates any other GGIO1 prefix that is used by the product such...

Page 286: ...ured and logical nodes re assigned The path is Settings Product Setup Communications IEC 61850 Logical Devices Figure 5 21 Default IEC 61850 Logical Devices panel with devices middle and nodes right To configure logical devices and nodes 1 Right click an entry and edit an existing device add a new one or move a logical node The rest of this section explains the window and how to perform these acti...

Page 287: ...nd editing the Protection logical device has been set to instance name Prot the function related name Feeder1Prot and the configuration revision 2016 03 07 08 46 The text is clipped on the right if the line is longer than the available width The next paragraphs explain how to do this setup Figure 5 22 Protection logical node selected Right clicking a logical device displays the menu that allows in...

Page 288: ...ue of the IED NAME setting When adding or editing a logical device entry these are the fields that need to be completed Product LD inst name Range 1 to 64 VisibleString characters Default as per the following table Each logical device has this setting The value is fixed at Master in the first logical device and configurable in all others Valid characters are upper and lowercase letters digits and ...

Page 289: ...hange in the presence of logical nodes data objects data attributes or instance names The scope of Maser configRev is the entire relay configuration as the Master logical device is the root logical device Similar settings are provided for the other logical nodes the scope of these other configRev settings is limited to the corresponding logical device configuration paramRev Range 2 147 483 648 to ...

Page 290: ...performed by a separate gateway device Messages are routed using a separate router using IP addresses Note the following behavior A v7 4 device can send an R GOOSE message to another v7 4 device when both have R GOOSE active as the protocol A v7 4 device can send a GOOSE message to another v7 4 device when both have GOOSE active as the protocol Each logical device has a name LDName Note the upper ...

Page 291: ...lass 3 ms while Booleans in the Normal datasets are designed for the TT3 class 100 ms Due to the significant amount of CPU time required to compose a TT6 TxGOOSE message and the limited amount of time allowed by the TT6 class at most four of these can be configured in a given UR So only four fast GOOSE are allowed to be configured and the UR software has a check to disallow the use of more than fo...

Page 292: ... 00 00 00 00 00 00 and cannot be changed TxGOOSE1 GoCB name Range 0 up to 32 VisibleString characters Default GoCB01 The entered value sets the GOOSE control block GoCB name value for TxGOOSE1 An ObjectReference to the control block which consists of the concatenation of the string LDName LLN0 and the control block name is published in the gocbRef field of TxGOOSE1 messages and is used by subscrib...

Page 293: ...s As the standard requires that the address have the multicast bit set TRUE that is to say the second digit is set to an odd number messages transmitted have the multicast bit set TRUE no matter its value in this setting The destination MAC address can be used by the network to restrict message delivery to selected devices that need to receive them reducing network load This address also can be us...

Page 294: ...le the set time If the entered time is zero only a single event transmission occurs then heartbeat transmissions resume TxGOOSE1 TIME TO LIVE Range 1 to 300 s in steps of 1 s Default 300 s The value entered sets the timeAllowedtoLive value in published TxGOOSE1 messages The standard requires subscribers to assume a failure has occurred when another TxGOOSE1 message is not received within the publi...

Page 295: ...850 GOOSE message subscribing service The publishing function in URs is performed by TxGOOSE elements as described in the previous section Each UR with the IEC 61850 order code option has 64 RxGOOSE elements Each RxGOOSE element can subscribe to GOOSE messages from a specified publisher Each RxGOOSE can either use the original format specified in IEC 61850 8 1 2011 or the routable GOOSE R GOOSE fo...

Page 296: ...are published in Routable GOOSE format according to IEC 61850 90 5 When set to R GOOSE the R RxGOOSE DST IP needs to be a valid multicast or unicast IP address RxGOOSE1 goID Range 0 to 129 Visible String characters Default empty string If the entered value has one or more characters the goID field of incoming GOOSE messages must exactly match this value for the message to be accepted as a valid Rx...

Page 297: ...f the publisher s IED NAME suffixed with Master If the publisher is a UR 7 3x series device GoCBName is GoCB suffixed with the two digit TxGOOSE instance number for example GoCB01 If the publisher is a UR 7 40 series device GoCBName is as specified earlier in the TxGOOSE section of this chapter RxGOOSE1 datSet Range 0 to 32 alphanumeric and underscore characters beginning with an alpha character D...

Page 298: ...55 255 in steps of 1 Default 224 0 0 0 When the RxGOOSE1 MODE setting is other than R GOOSE the value of this setting is not used Otherwise the Destination IP Address field of incoming R GOOSE messages must exactly match this value for the message to be accepted as a valid RxGOOSE1 message Set this setting to the same value as the R GOOSE publisher s Destination IP Address For UR publishers this v...

Page 299: ...value of a specified FLOAT32 member to a FlexAnalog operand Each of these operands reverts to its default state when the RxGOOSE connectivity is lost Other types of values can be present in subscribed GOOSE messages but cannot be converted to operands An RxGOOSE Input that is mapped to a value that in the GOOSE message is a child of a data object reverts to its configured default value while the Q...

Page 300: ... FlexLogic operand If set to None the RxGOOSE Boolean1 FlexLogic operand assumes its default state RxGOOSE Boolean1 Member Range 1 to 64 in steps of 1 Default 1 This setting selects the GOOSE message member that drives the RxGOOSE Boolean1 FlexLogic operand A setting of 1 selects the first member 2 selects the second member and so on Entering a number greater than the number of members in the mess...

Page 301: ...itions are never recorded even if events are enabled RxGOOSE DPS inputs Navigate to Settings Product Setup Communications IEC 618560 GOOSE RxGOOSE RxGOOSE DPS Inputs There are Add IED and Remove IED buttons The Add IED button allows SCL files to be used including ICD CID and SCD supported in version 7 40 and later When the file format is SCD the system lists all IEDs inside the SCD file and lets t...

Page 302: ...as not yet received a message and when the RxGOOSE has lost its connection with the publisher When this setting is selected to Latest the value of Master GGIO3 IndPosψψ stVal is Intermediate state when the UR has just completed start up and the selected RxGOOSE has not yet received a message and the latest received value when the RxGOOSE loses its connectivity with the publisher RxGOOSE DPS1 EVENT...

Page 303: ...to the closest possible floating point number RxGOOSE Analog1 DEFAULT MODE Range Default Value Last Known Default Default Value When the selected RxGOOSE has lost its connectivity with the publisher and this setting is Last Known the value of the RxGOOSE Analog1 FlexLogic operand remains at the last received value When the selected RxGOOSE has lost its connectivity with the publisher and this sett...

Page 304: ...Settings rptID Range Dyn Conf Default Dyn When set to Dyn the RptID attribute in any buffered and unbuffered report control block can be modified by an MMS client while the control block s RptEna attribute is false The RptID is the name of the report ReportSettings optFields Range Dyn Conf Default Dyn When set to Dyn the OptFlds attribute in any buffered and unbuffered report control block can be ...

Page 305: ...s that occur while the client is not connected are lost Table 5 11 Number of report elements Configurable Reports interoperate with any client device of any manufacturer that conforms to the IEC 61850 edition 1 0 or 2 0 report client requirements The entities whose values are reported by a Configurable Report are known as members The members are itemized in an ordered list known as a data set Each...

Page 306: ...cribed later An ObjectReference to the data set which consists of the concatenation of the string LDName LLN0 and the data set name is used in the datSet field of report messages and it can be used by the client to discriminate Buffered Report1 messages from other messages The performance of the report is determined by the performance of the selected dataset When the selection is TT3DataSet01 TT3D...

Page 307: ...es the values of all members of the referenced data set whether a change has occurred or not Each unbuffered report has the following settings Unbuffered Report1 RptID Range 0 to 129 VisibleString characters Default empty string The name of the report The entered value sets the RptID value in Unbuffered Report1 messages and it can be used by the client to discriminate Unbuffered Report1 messages f...

Page 308: ...ing is bitstring that controls which of the optional fields are included in report messages The options are as follows To reduce message size uncheck any fields that are not needed sequence number report time stamp reason for inclusion data set name data reference conf revision The OptFlds bits buffer overflow and entryID also listed are not applicable to unbuffered reports even though the bits ex...

Page 309: ... also provide a chatter suppression service for their Boolean members Oscillation in a value also known as chatter can be caused by errors in logic programming inadequate hysteresis deadband on a threshold or a failed station component Chatter can flood a communications network with GOOSE messages degrading response time for all users If chatter is detected in a Boolean member TxGOOSE suspends GOO...

Page 310: ... used by subscribers to discriminate the messages of that TxGOOSE from other GOOSE messages An ObjectReference to the data set is optionally published in the DatSet field of Report messages Valid characters are upper and lowercase letters digits and the underscore _ character The first character must be a letter DataSet01 shared by Range 0 to 32 VisibleString characters Default Names of all contro...

Page 311: ...mmands to SecGSAL1 SecDataClr sbo here is select before operate SecGSAL1 OpCntRs ctlModel Range direct with normal security sbo with normal security Default direct with normal security This setting selects the control model that clients must use to clear security data via commands to SecGSAL1 OpCntRs sbo here is select before operate Demand Deadband parameters of measured values related to the Dem...

Page 312: ...lue of 500000000 500000000 0 002 100 20000 ns The default setting value of 0 000 does not update the mag and cVal values Deadband settings A deadband is a range in which no action occurs usually expressed as a percentage The IEC 61850 panels contain hundreds of deadband settings such as in the following panels Product Setup Real Time Clock FlexLogic Control Elements and GGIO4 Each panel is not out...

Page 313: ...g db in the figure Changes to this deadbanded value trigger transmissions when included in GOOSE and report data sets Figure 5 39 Deadband settings Deadband settings are entered in UR Setup software in units of percent of the difference between the max and min of the associated analog value A zero deadband setting suppresses transmission triggering The range of deadband settings is 0 000 to 100 00...

Page 314: ...ertain settings that configure how the IEC 61850 protocol interacts with these elements These settings are described in this section See the Breakers section in the System Setup section of this chapter for details on the operation of breaker control elements Navigate to Settings Communications IEC 61850 System Setup Breakers Breaker 1 to access the settings that configure the IEC 61850 protocol in...

Page 315: ...1 Pos or Bkr0XCBR1 Pos and the selected operand is not activated a Negative Response Rsp is issued with the REASON CODE of Blocked by interlocking XCBR1 Pos ctlModel Range status only direct with normal security sbo with normal security direct with enhanced security sbo with enhanced security Default sbo with enhanced security This setting selects the control model clients must use to successfully...

Page 316: ... XCBR1 ST LOC OPERAND is not active CSWI1 Pos sboTimeout Range 2 to 60 s in steps of 1 s Default 30 s This setting specifies the maximum time between a select and an operate command to breaker 1 via BkrCSWI1 Pos in order for the operand to be successful This setting is only relevant when CSWI1 Pos ctlModel is sbo with normal security or sbo with enhanced security CSWI1 Pos operTimeout Range 0 000 ...

Page 317: ...ocked by interlocking XSWI1 INTERLOCK CLS Range any FlexLogic operand Default ON This setting is used to select a FlexLogic operand that declares to IEC 61850 services that interlocking conditions are not acceptable for closing disconnect switch 1 While the selected operand is asserted the value of DiscCILO EnaCls stVal is false If a SelectWithValue or Operate service with ctlVal true and with Che...

Page 318: ... Range status only direct with normal security sbo with normal security direct with enhanced security sbo with enhanced security Default direct with normal security This setting selects the control model clients must use to successfully control the disconnect switch 1 signals marked DiscCSWI1 PosOpn ctlVal and DiscCSWI1 PosCls ctlVal on the Disconnect Switch Logic diagram in the Settings System Se...

Page 319: ...CID file This setting is not mapped into the IEC 61850 information model but sets the value of SettingControl element attribute actSG in SCL files Commands The UR implements a number of clear records commands as detailed in the Commands and Targets chapter of this manual Several of these commands also can be issued via IEC 61850 The settings related to these IEC 61850 commands are described here N...

Page 320: ...normal security sbo with normal security Default direct with normal security This setting selects the control model clients must use to successfully control the command CLEAR OSCILLOGRAPHY DatLogRDRE1 MemClr ctlModel Range direct with normal security sbo with normal security Default direct with normal security This setting selects the control model clients must use to successfully control the comm...

Page 321: ... FlexLogic operands GGIO1 INDICATION 2 Range any FlexLogic operand Default OFF Selects the FlexLogic operand mapped to LDName GGIO1 Ind002 stVal and so on GGIO2 Virtual Inputs are controllable FlexLogic operands that can be controlled via IEC 61850 commands to GGIO2 by DNP by Modbus and by the UR front panel The settings related to these IEC 61850 commands are described here Navigate to Settings P...

Page 322: ...cluded in TxGOOSE messages or included in buffered unbuffered reports the value must be assigned to a data attribute GGIO4 allows those FlexAnalog operands that have not yet been factory assigned to a data attribute to be user assigned to a generic data attribute and thus have their values included in IEC 61850 communications Navigate to Settings Product Setup Communications IEC 61850 GGIO GGIO4 G...

Page 323: ...ues can be stored Some values are rounded to the closest possible floating point number ANALOG IN 1 MAX Range 1000000000 000 to 1000000000 000 in steps of 0 001 Default 1000000 000 This setting specifies the max value used in deadband calculations The scaling of this setting is the same as used by LDName GGIO4 AnIn01 instMag f This setting is stored as an IEEE 754 IEC 60559 floating point number B...

Page 324: ...e organized as a series of menus that can be accessed starting at the L90 Main Menu Web pages are read only and are available showing DNP and IEC 60870 5 104 points lists Modbus registers event records fault reports and so on First connect the L90 and a computer to an Ethernet network then enter the IP address of the L90 Ethernet port in a web browser To close the port set the port number to 0 Any...

Page 325: ...ou can enter a get command but not a put command TFTP MAIN UDP PORT NUMBER To close the port set the port number to 0 Any change takes effect when the L90 is restarted 5 3 5 15 IEC 60870 5 104 protocol SETTINGS PRODUCT SETUP COMMUNICATIONS IEC 60870 5 104 PROTOCOL Do not set more than one protocol to the same TCP UDP port number as this results in unreliable operation of those protocols TFTP PROTO...

Page 326: ... to change threshold values from the default for each individual M_ME_NC_1 analog point Whenever power is removed and re applied to the L90 the default thresholds are in effect The IEC REDUNDANCY setting decides whether multiple client connections are accepted or not If redundancy is set to Yes two simultaneous connections can be active at any given time IEC TCP PORT NUMBER To close the port set t...

Page 327: ...ations Guide contains more information on the protocol IEC103 COMMON ADDRESS OF ASDU This setting uniquely defines this L90 on the serial line Select an ID between 0 and 254 This ID does not need to be in sequential order for all stations that communicate with a controller but it is recommended Note that RS485 only allows a maximum of 32 slave stations on a communication line so the entire range o...

Page 328: ...neral interrogation received from the controller or reported spontaneously Spontaneous transmission occurs as a response to cyclic Class 2 requests If the L90 wants to transmit Class 1 data at that time it demands access for Class 1 data transmission ACD 1 in the control field of the response For any change to take effect restart the relay SETTINGS PRODUCT SETUP COMMUNICATIONS IEC 60870 5 103 IEC1...

Page 329: ...d ASDU is included in a response The measurand is sent as response to a Class 2 request when the corresponding timeout expires The default value 0 means 500 ms ASDU 1 ANALOG 1 Off Range FlexAnalog parameter ASDU 1 ANALOG 1 FACTOR 1 000 Range 0 000 to 65 535 in steps of 0 001 ASDU 1 ANALOG 1 OFFSET 0 Range 32768 to 32767 in steps of 1 ASDU 1 ANALOG 9 Off Range FlexAnalog parameter ASDU 1 ANALOG 9 F...

Page 330: ...ing is done By default a 1 and b 0 so no scaling is done if these values are left at their defaults Examples of when scaling is appropriate are as follows If the measured value contains decimals and it is important to preserve the resolution Since the format for transmitting the measurand does not permit decimals a factor a 1 can be applied before transmission For example a frequency F 59 9Hz can ...

Page 331: ...master sends an ASDU command that does not have the FUN and INF of any configured command the relay rejects it Table 5 12 Commands mapping table For any change to take effect restart the relay 5 3 5 17 USB port SETTINGS PRODUCT SETUP COMMUNICATIONS USB 2 0 IEC103 COMMANDS COMMAND 0 See below COMMAND 1 COMMAND 31 COMMAND 0 COMMAND 0 FUN 0 Range 0 to 255 in steps of 1 COMMAND 0 INF 0 Range 0 to 255 ...

Page 332: ...Different ADDRESS values can be entered as required in any of the register positions The UR Family Communications Guide outlines the Modbus memory map The map is also viewable in a web browser enter the IP address of the L90 in a web browser and click the option 5 3 7 Real time clock 5 3 7 1 Menu SETTINGS PRODUCT SETUP REAL TIME CLOCK The relay contains a real time clock RTC to create time stamps ...

Page 333: ...e low accuracy time synchronization methods avoid their use for synchronization when better accuracy time protocols such as IRIG B and PTP are active in the system If IRIG B or PTP is used to update the relay clock the other protocols such as SNTP are not allowed to update even if active See the COMMANDS SET DATE AND TIME menu section of this manual to manually set the RTC The REAL TIME CLOCK EVEN...

Page 334: ...all others make themselves slaves and track the grandmaster Typically the grandmaster clock receives its time from GPS satellites or some other link to the international time standard If the grandmaster fails the next best clock available in the domain assumes the grandmaster role When a clock on start up discovers that it is better than the present grandmaster it assumes the grandmaster role and ...

Page 335: ...elected to disabled PTP is disabled on this port The relay does not generate or listen to PTP messages on this port PORT 1 3 PATH DELAY ADDER The time delivered by PTP is advanced by the time value in this setting prior to the time being used to synchronize the relay s real time clock This is to compensate to the extent practical for time delivery delays not compensated for in the network In a ful...

Page 336: ...al time and Universal Coordinated Time UTC Local time can be provided by IRIG B signals UTC time is provided by SNTP servers The real time clock RTC and time stamps reported in historical records and communication protocols can be incorrect if the Local Time settings are not configured properly See the IRIG B section in the Installation chapter for guidance on these settings when using an IRIG B s...

Page 337: ...nge 0 01 to 250 00 ohms in steps of 0 01 FAULT REPORT 1 Z1 ANGLE 75 Range 25 to 90 in steps of 1 FAULT REPORT 1 Z0 MAG 9 00 Ω Range 0 01 to 650 00 ohms in steps of 0 01 FAULT REPORT 1 Z0 ANGLE 75 Range 25 to 90 in steps of 1 FAULT REPORT 1 Z0M MAG 0 00 Ω Range 0 00 to 650 00 ohms in steps of 0 01 FAULT REPORT 1 Z0M ANGLE 0 Range 25 to 90 in steps of 1 FAULT REPORT 1 LINE LENGTH UNITS km Range km m...

Page 338: ...ents Nine before trigger and seven after trigger only available via the relay web page Fault duration times for each breaker created by the breaker arcing current feature The captured data also includes the fault type the distance to the fault location distance to the fault location fault loop impedance as well as the reclose shot number when applicable To include fault duration times in the fault...

Page 339: ...r fault location calculations For the application of entirely parallel lines Z0M MAG ANG is the mutual zero sequence impedance for the whole line required to compensate the calculation of fault resistance and fault loop impedance For a three terminal application these settings are used to enter the line segment impedance and length from the local terminal to the tap point only The figure shows the...

Page 340: ...raphy records are triggered by a programmable FlexLogic operand Multiple oscillography records can be captured simultaneously When EnerVista UR Setup creates a new settings file a Smart defaults feature automatically enters a basic oscillography configuration The basic configuration changes the factory default values to make the number of samples per cycle 32 adds a selection of digital and analog...

Page 341: ...y which is always 64 samples per cycle That is it has no effect on the fundamental calculations of the device 5 3 9 2 Digital channels SETTINGS PRODUCT SETUP OSCILLOGRAPHY DIGITAL CHANNELS DIGITAL 1 63 CHANNEL This setting selects the FlexLogic operand state recorded in an oscillography trace The length of each oscillography trace depends in part on the number of parameters selected here Parameter...

Page 342: ...nal 2 of the CT VT module in slot F If there are no CT VT modules and analog input modules no analog traces appear in the file only the digital traces appear 5 3 10 Data logger SETTINGS PRODUCT SETUP DATA LOGGER The data logger samples and records up to 16 analog parameters at a user defined sampling rate This recorded data can be downloaded to EnerVista UR Setup and displayed with parameters on t...

Page 343: ...ng actual value that is to be recorded in Channel 1 16 of the data log The parameters available in a given relay are dependent on the type of relay the type and number of CT VT hardware modules installed and the type and number of Analog Input hardware modules installed Upon startup the relay automatically prepares the parameter list A list of all possible analog metering actual value parameters i...

Page 344: ...e t in minutes D input quantity constant k 2 3 thermal 90 response time The figure shows the 90 thermal response time characteristic of 15 minutes A setpoint establishes the time to reach 90 of a steady state value just as the response time of an analog instrument A steady state value applied for twice the response time indicates 99 of the value Figure 5 51 Thermal demand characteristic 5 3 11 2 C...

Page 345: ...ustomized in a similar manner To ensure correct functionality of all LEDs an LED test feature is also provided 5 3 12 3 LED test SETTINGS PRODUCT SETUP USER PROGRAMMABLE LEDS LED TEST If no trigger is assigned in the DEMAND TRIGGER setting and the CRNT DEMAND METHOD is Block Interval use calculation method 2 If a trigger is assigned the maximum allowed time between two trigger signals is 60 minute...

Page 346: ...the orange color for one second then back off The test routine starts at the top left panel moving from the top to bottom for all 14 LEDs Then the eight pushbutton LEDs are tested in the same manner This test checks for hardware failures that lead to more than one LED being turned on from a single logic point This stage can be interrupted at any time 3 All the LEDs are turned on with the orange co...

Page 347: ... LED TEST menu LED TEST FUNCTION Enabled LED TEST CONTROL PUSHBUTTON 1 ON The test is initiated when the user programmable pushbutton 1 is pressed Keep the pushbutton pressed for as long as the LEDs are being visually inspected When finished release the pushbutton The relay then automatically starts stage 2 At this point test can be cancelled by pressing the pushbutton Application example 2 Assume...

Page 348: ...these indexed LEDs The user programmable LED settings select the FlexLogic operands that control the LEDs If the LED 1 TYPE setting is Self Reset the default setting the LED illumination tracks the state of the selected LED operand If the LED 1 TYPE setting is Latched the LED once lit remains so until reset by the front panel RESET button from a remote device via a communications channel or from a...

Page 349: ...ESTS EVENT CAUSE LED 1 LED 1 OPERAND LED PICKUP Range FlexLogic operand LED 1 COLOR Green Range Red Green Orange LED 1 TYPE Self Reset Range Self Reset Latched LED Default input operand Output operand Default color Event Cause LED 1 LED PICKUP EVENT CAUSE LED 1 Green Event Cause LED 2 LED VOLTAGE EVENT CAUSE LED 2 Orange Event Cause LED 3 LED CURRENT EVENT CAUSE LED 3 Orange Event Cause LED 4 LED ...

Page 350: ... with enhanced and standard front panels There are three standard control pushbuttons labelled USER 1 USER 2 and USER 3 on the standard and enhanced front panels These are user programmable and can be used for various applications such as performing an LED test switching setting groups and invoking and scrolling though user programmable displays Firmware revisions 3 2x and older use these three pu...

Page 351: ...e control pushbuttons as inputs An event is logged in the event record as per user setting when a control pushbutton is pressed No event is logged when the pushbutton is released The front panel keys including control keys cannot be operated simultaneously a given key must be released before the next one can be pressed The control pushbuttons become user programmable only if the breaker control fe...

Page 352: ...et pushbutton 1 to clear event records The user programmable pushbuttons are under the control level of password protection PUSHBTN 1 ON TEXT Range up to 20 alphanumeric characters PUSHBTN 1 OFF TEXT Range up to 20 alphanumeric characters PUSHBTN 1 HOLD 0 0 s Range 0 0 to 10 0 s in steps of 0 1 PUSHBTN 1 SET Off Range FlexLogic operand PUSHBTN 1 RESET Off Range FlexLogic operand PUSHBTN 1 AUTORST ...

Page 353: ...e pushbuttons standard front panel Figure 5 58 User programmable pushbuttons graphical front panel Front panel pushbuttons and LEDs can be custom labelled as outlined in the Front Panel Labelling section in the previous chapter Each pushbutton asserts its own On and Off FlexLogic operands for example PUSHBUTTON 1 ON and PUSHBUTTON 1 OFF These operands are available for each pushbutton and are used...

Page 354: ... and reset commands executed through FlexLogic operands The inhibit functions are not applied to the autoreset feature The inhibit function can be used in SBO control operations to prevent user programmable pushbutton activation and ensuring one at a time select operation The inhibit functions can also be used to prevent pushbutton activation from the accidental pressing of the front panel pushbut...

Page 355: ...pecifies the time delay for automatic reset of the pushbutton when in Latched mode PUSHBTN 1 REMOTE This setting assigns the FlexLogic operand serving to inhibit user programmable pushbutton operation from the operand assigned to the PUSHBTN 1 SET or PUSHBTN 1 RESET settings PUSHBTN 1 LOCAL This setting assigns the FlexLogic operand serving to inhibit user programmable pushbutton operation from th...

Page 356: ... L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL PRODUCT SETUP CHAPTER 5 SETTINGS 5 The figures show the user programmable pushbutton logic Figure 5 59 User programmable pushbutton logic Sheet 1 of 2 ...

Page 357: ...o the FlexLogic operand states in the relay The state bits are packed so that 16 states are readable in a single Modbus register The state bits can be configured so that all states of interest are available in a minimum number of Modbus registers The state bits can be read out in the Flex States register array beginning at Modbus address 0900h Sixteen states are packed into each register with the ...

Page 358: ...e pushbutton is pressed the displays are invoked by showing the last user definable display shown during the previous activity From this moment onward the operand acts exactly as the down key and allows scrolling through the configured displays The last display wraps up to the first one The INVOKE AND SCROLL input and the down arrow key operate concurrently When the default timer expires set by th...

Page 359: ...rm of the Modbus address then manually convert it to decimal form before entering it EnerVista usage conveniently facilitates this conversion Use the MENU key to go to the user displays menu to view the user defined content The current user displays show in sequence changing every four seconds While viewing a user display press the ENTER key and then select the Yes option to remove the display fro...

Page 360: ...sformers The L90 with a process bus module has access to all of the capabilities of up to eight Bricks Remote resources settings configure the point to point connection between specific fiber optic ports on the L90 process card and specific Brick The relay is then configured to measure specific currents voltages and contact inputs from those Bricks and to control specific outputs The configuration...

Page 361: ...he three phase currents IA IB IC neutral current 3Io is used as the input for the neutral overcurrent elements In addition a zero sequence core balance CT which senses current in all of the circuit primary conductors or a CT in a neutral grounding conductor can also be used For this configuration the ground CT primary rating must be entered To detect low level ground fault currents the sensitive g...

Page 362: ... CONNECTION Wye Range Wye Delta PHASE VT F5 SECONDARY 66 4 V Range 25 0 to 240 0 V in steps of 0 1 PHASE VT F5 RATIO 1 00 1 Range 1 00 to 24000 00 in steps of 0 01 AUXILIARY VT F5 CONNECTION Vag Range Vn Vag Vbg Vcg Vab Vbc Vca AUXILIARY VT F5 SECONDARY 66 4 V Range 25 0 to 240 0 V in steps of 0 1 AUXILIARY VT F5 RATIO 1 00 1 Range 1 00 to 24000 00 in steps of 0 01 The nominal PHASE VT F5 SECONDAR...

Page 363: ...erence signal always displays zero degrees and all other phase angles are relative to this signal If the pre selected reference signal is not measurable at a given time the phase angles are not referenced The phase angle referencing is done via a phase locked loop which can synchronize independent UR series relays if they have the same AC signal reference This results in very precise correlation o...

Page 364: ... parameters from the available inputs Users must select the specific input parameters to be measured by every element in the relevant settings menu The internal design of the element specifies which type of parameter to use and provides a setting for source selection In elements where the parameter can be either fundamental or RMS magnitude such as phase time overcurrent two settings are provided ...

Page 365: ... disturbance detector accordingly 5 5 3 4 Example for use of sources An example of the use of sources is shown in the following figure A relay can have the following hardware configuration This configuration can be used on a two winding transformer with one winding connected into a breaker and a half system The following figure shows the arrangement of sources used to provide the functions require...

Page 366: ...TINGS SYSTEM SETUP 87L POWER SYSTEM Y LV D HV AUX SRC 1 SRC 2 SRC 3 Phase CT M1 F1 F5 None Ground CT M1 None None Phase VT M5 None None Aux VT None None U1 87L POWER SYSTEM NUMBER OF TERMINALS 2 Range 2 3 NUMBER OF CHANNELS 1 Range 1 2 CHARGING CURRENT COMPENSATN Disabled Range Disabled Enabled POS SEQ CAPACITIVE REACTANCE 0 100 kΩ Range 0 100 to 65 535 kΩin steps of 0 001 ...

Page 367: ... it is critical to ensure that three phase line voltage is assigned to this source The figure shows possible configurations ZERO SEQ CAPACITIVE REACTANCE 0 100 kΩ Range 0 100 to 65 535 kΩ in steps of 0 001 ZERO SEQ CURRENT REMOVAL Disabled Range Disabled Enabled LOCAL RELAY ID NUMBER 0 Range 0 to 255 in steps of 1 TERMINAL 1 RELAY ID NUMBER 0 Range 0 to 255 in steps of 1 TERMINAL 2 RELAY ID NUMBER...

Page 368: ...as follows Three reactor arrangement Three identical line reactors Xreact solidly connected phase to ground Eq 5 8 Four reactor arrangement Three identical line reactors Xreact wye connected with the fourth reactor Xreact_n connected between reactor bank neutral and the ground Eq 5 9 where X1line_capac the total line positive sequence capacitive reactance X0line_capac the total line zero sequence ...

Page 369: ...of a relay if the channel is inadvertently set to loopback mode by recognizing its own ID on a received channel If an incorrect ID is found on a either channel during normal operation the FlexLogic operand 87 CH1 2 ID FAIL is set driving the event with the same name The result of channel identification is also available in ACTUAL VALUES STATUS CHANNEL TESTS VALIDITY OF CHANNEL CONFIGURATION for co...

Page 370: ...he round trip travel time This value is measured by the L90 and a user programmable threshold applied to it The corresponding FlexLogic operands are produced if the delta change is above the threshold 87L DIFF 1 TIME CHNG and 87L DIFF 2 TIME CHNG These operands can be latched in FlexLogic and combined with other factors to decide upon GPS loss if the relays continue to compensate using the memoriz...

Page 371: ...nchronized to the selected synchronizing source This can possibly occur on power up when transferring between sources and when the selected source s holdover timer times out The quality bits in the messages from a PTP source used for synchronizing indicate worst case error greater than 250 µs or accuracy less than 250 µs or unknown accuracy error that is not locked to an international time standar...

Page 372: ...SYSTEM SETUP CHAPTER 5 SETTINGS 5 Figure 5 65 Channel asymmetry compensation logic 5 5 4 2 In zone transformer SETTINGS SYSTEM SETUP 87L POWER SYSTEM IN ZONE TRANSFORMER IN ZONE TRANSFORMER IN ZONE TRANSFORMER CONNECTION None Range None 0 to 330 lag in steps of 30 ...

Page 373: ...mer is allowed for both two terminal and three terminal applications Enabling in zone transformer functionality forces the L90 to automatically remove the zero sequence component from all terminals currents It also disables ground differential 87LG functionality and zero sequence current removal functionality defined by the ZERO SEQ CURRENT REMOVAL setting Do not set the IN ZONE TRANSFORMER CONNEC...

Page 374: ...R 1 OPEN Off Range FlexLogic operand BREAKER 1 BLK OPEN Off Range FlexLogic operand BREAKER 1 CLOSE Off Range FlexLogic operand BREAKER 1 BLK CLOSE Off Range FlexLogic operand BREAKER1 ΦA 3P CLSD Off Range FlexLogic operand BREAKER1 ΦA 3P OPND Off Range FlexLogic operand BREAKER 1 ΦB CLOSED Off Range FlexLogic operand BREAKER 1 ΦB OPENED Off Range FlexLogic operand BREAKER 1 ΦC CLOSED Off Range Fl...

Page 375: ...element or BREAKER 1 OPEN setting is not affected BREAKER1 SUBSTITUTN Set to Enable to allow the graphical front panel to substitute breaker 1 status When substituted breaker 1 control open close status is forced to the substituted value BREAKER1 BYPASS Set to Enable to allow the graphical front panel to bypass breaker 1 interlocking When asserted BREAKER 1 BLK OPEN and BREAKER 1 BLK CLOSE setting...

Page 376: ...d as three pole this setting has no function If the mode is selected as single pole this input is used to track the breaker phase C closed position as outlined for phase A BREAKER 1 ΦC OPENED If the mode is selected as three pole this setting has no function If the mode is selected as single pole this input is used to track the breaker phase C opened position as outlined for phase A BREAKER 1 TOPE...

Page 377: ...CHAPTER 5 SETTINGS SYSTEM SETUP L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 153 5 Figure 5 67 Dual breaker control logic Sheet 1 of 3 ...

Page 378: ...5 154 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL SYSTEM SETUP CHAPTER 5 SETTINGS 5 Figure 5 68 Dual breaker control logic Sheet 2 of 3 ...

Page 379: ...ng with blocking of open close commands are provided Note that the dwell time for the IEC 61850 trip and close commands shown is one protection pass only To maintain the close open command for a certain time do so by setting the seal in timers BREAKER 1 OPEN SEAL IN and MANUAL CLOSE RECAL1 TIME on the contact outputs using the Seal in setting in the Trip Output element and or in FlexLogic 5 5 6 Di...

Page 380: ...e disconnect switch This name is used in flash messages related to disconnect switch 1 SWITCH 1 MODE This setting selects 3 Pole mode where disconnect switch poles have a single common auxiliary switch or 1 Pole mode where each disconnect switch pole has its own auxiliary switch SWITCH 1 BLK OPEN Off Range FlexLogic operand SWITCH 1 CLOSE Off Range FlexLogic operand SWITCH 1 BLK CLOSE Off Range Fl...

Page 381: ...de is selected as three pole this setting has no function If the mode is selected as single pole this input is used to track the disconnect switch phase B opened position as outlined for phase A SWITCH 1 ΦC CLOSED If the mode is selected as three pole this setting has no function If the mode is selected as single pole this input is used to track the disconnect switch phase C closed position as out...

Page 382: ...nality local remote switch functionality along with blocking open close commands are provided Note that the dwell time for the IEC 61850 trip and close commands shown is one protection pass only To maintain close open command for a certain time do so using the seal in timers SWITCH 1 OPEN SEAL IN and SWITCH 1 CLOSE SEAL IN on the contact outputs using the Seal in setting or in FlexLogic Figure 5 7...

Page 383: ...CHAPTER 5 SETTINGS SYSTEM SETUP L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 159 5 Figure 5 71 Disconnect switch control status logic sheet 2 of 3 ...

Page 384: ...g pickup levels 0 00 to 0 98 and 1 03 to 20 00 This data is converted into two continuous curves by linear interpolation between data points To enter a custom FlexCurve enter the reset and operate times using the VALUE keys for each selected pickup point using the MESSAGE up down keys for the required protection curve A B C or D FLEXCURVE A FLEXCURVE A TIME AT 0 00 xPKP 0 ms Range 0 to 65535 ms in...

Page 385: ... definite operating times are useful to coordinate operating times typically at higher currents and where upstream and downstream protective devices have different operating characteristics The recloser curve configuration window shown here appears when the Initialize From setting in the EnerVista software is set to Recloser Curve and the Initialize FlexCurve button is clicked Reset Time ms Reset ...

Page 386: ...ms At approximately four times pickup the curve operating time is equal to the MRT and from then onwards the operating time remains at 200 ms Figure 5 74 Composite recloser curve with HCT disabled With the HCT feature enabled the operating time reduces to 30 ms for pickup multiples exceeding eight times pickup The Multiplier and Adder settings only affect the curve portion of the characteristic an...

Page 387: ... Standard recloser curves The following graphs display standard recloser curves available for the L90 Figure 5 76 Recloser curves GE101 to GE106 Configuring a composite curve with an increase in operating time at increased pickup multiples is not allowed If this is attempted the EnerVista software generates an error message and discards the proposed changes ...

Page 388: ...L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL SYSTEM SETUP CHAPTER 5 SETTINGS 5 Figure 5 77 Recloser curves GE113 GE120 GE138 and GE142 Figure 5 78 Recloser curves GE134 GE137 GE140 GE151 and GE201 ...

Page 389: ... SETTINGS SYSTEM SETUP L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 165 5 Figure 5 79 Recloser curves GE131 GE141 GE152 and GE200 Figure 5 80 Recloser curves GE133 GE161 GE162 GE163 GE164 and GE165 ...

Page 390: ...RENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL SYSTEM SETUP CHAPTER 5 SETTINGS 5 Figure 5 81 Recloser curves GE116 GE117 GE118 GE132 GE136 and GE139 Figure 5 82 Recloser curves GE107 GE111 GE112 GE114 GE115 GE121 and GE122 ...

Page 391: ...ion operation and control can be realized when synchrophasors from different locations within the power system are networked to a central location The L90 offers PMU features over two communication standards IEC 61850 90 5 and IEEE C37 118 The figure shows complete synchrophasor implementation PHASOR MEASUREMENT UNIT PHASOR MEASUREMENT UNIT 1 See below PMU AGGREGATOR 1 See page 5 184 IEC 90 5 MSVC...

Page 392: ...based R SV implementation equivalent in structure and configuration to that of the existing IEEE C37 118 implementation of firmware version 6 0 that is synchrophasor data at rates up to 60 Hz for metering and 120 Hz for protection class synchrophasors The following two figures depict the general data flow for the generation of synchrophasor data for IEC 61850 90 5 In the first figure when IEC 6185...

Page 393: ...xxMMXU MxxMSQI PxxxMMXU PxxxMSQI NxxMMXU and one NxxMSQI logical node Figure 5 86 Logical nodes supported in each logical device The following is a summary of LNs that are in each Logical Device LD2 through LD7 PxxxMMXU1 ClcMth P Class Note Vaux is mapped to Vneut of MMXU PxxxMSQI1 ClcMth P CLASS MxxMMXU1 ClcMth M Class Note Vaux is mapped to Vneut of MMXU MxxMSQI1 ClcMth M CLASS NxxMMXU1 ClcMth M...

Page 394: ...60 frames second This example gives the protection synchrophasors data set with a reporting rate of 60 frames per second P60MMXU1 See the figure earlier Logical Nodes Supported in Each Logical Device This data or list of items as shown in the following figure is not available to the UR setup program but is available to be mapped by the user into a selected aggregator or aggregators dataset The log...

Page 395: ...a sets 5 5 8 6 Configuration example CFG 2 based configuration using IEC 61850 90 5 The L90 is expected to send the CFG 2 file IEEE C37 118 config file upon request from the upstream synchrophasor devices for example P30 without stopping R SV multicasting as shown in the following figure The primary domain controller PDC does not need to use a stop start data stream command if the UR protocol is s...

Page 396: ...FG 2 file found in bits 0 3 of the frame SYNC word which is set presently to 2 is set as follows 5 5 8 8 Settings The PMU settings are organized as follows SETTINGS SYSTEM SETUP PHASOR MEASUREMENT UNIT PHASOR MEASUREMENT UNIT 1 5 5 8 9 Basic configuration SETTINGS SYSTEM SETUP PHASOR MEASUREMENT UNIT BASIC CONFIGURATION PMU 1 Value decimal Number of ASDUs 11 1 12 2 13 3 14 4 PHASOR MEASUREMENT UNI...

Page 397: ...ues PMU 1 PHS 14 Off Range available synchrophasor values PMU 1 PHS 1 NM GE UR PMU PHS 1 Range 16 character ASCII string PMU 1 PHS 14 NM GE UR PMU PHS 14 Range 16 character ASCII string PMU 1 A CH 1 Off Range available FlexAnalog values PMU 1 A CH 8 Off Range available FlexAnalog values PMU 1 A CH 1 NM AnalogChannel 1 Range 16 character ASCII string PMU 1 A CH 8 NM AnalogChannel 8 Range 16 charact...

Page 398: ...ng complies with bit 1 of the FORMAT field of the C37 118 configuration frame Note that this setting applies to synchrophasors only the user selectable FlexAnalog channels are always transmitted as 16 bit integer values PMU 1 NETWORK REPORTING STYLE This setting selects between reporting synchrophasors in rectangular real and imaginary or in polar magnitude and angle coordinates This setting compl...

Page 399: ...orresponding to the digital channel 1 and byte 2 MSB corresponding to digital channel 16 PMU 1 D CH 1 NM to PMU 1 D CH 16 NM These settings allow for custom naming of the digital channels Sixteen character ASCII strings are allowed as in the CHNAM field of the configuration frame PMU 1 D CH 1 NORMAL STATE to PMU 1 D CH 16 NORMAL STATE These settings allow for specifying a normal state for each dig...

Page 400: ...0 in steps of 0 05 PMU 1 VA CALIBRATION MAG 100 0 Range 95 0 to 105 0 in steps of 0 1 PMU 1 VB CALIBRATION ANGLE 0 00 Range 5 00 to 5 00 in steps of 0 05 PMU 1 VB CALIBRATION MAG 100 0 Range 95 0 to 105 0 in steps of 0 1 PMU 1 VC CALIBRATION ANGLE 0 00 Range 5 00 to 5 00 in steps of 0 05 PMU 1 VC CALIBRATION MAG 100 0 Range 95 0 to 105 0 in steps of 0 1 PMU 1 VX CALIBRATION ANGLE 0 00 Range 5 00 t...

Page 401: ...he negative sequence voltage angle Note that When this setting is not 0 the phase and sequence voltages do not agree Unlike sequence voltages the phase voltages cannot be corrected in a general case and therefore are reported as measured When receiving synchrophasor data at multiple locations with possibly different reference nodes it can be more beneficial to allow the central locations to perfor...

Page 402: ...is available for all five triggering functions FREQ ROCOF VOLT CURR POWER in individual trigger settings under the TRIGGER DPO TIME setting This asserts individual trigger operand and overall PMU x TRIGGERED operand with stat bits 3 and 11 for a fixed interval defined by this setting If it is required that PMU x TRIGGERED operand with stat bits 3 and 11 stay longer than the individual reset timer ...

Page 403: ...recorder PMU 1 FREQ TRIGGER DPO TIME Use to extend the trigger after the situation returns to normal This setting is of importance when using the recorder in the forced mode recording as long as the triggering condition is asserted Figure 5 91 Frequency trigger logic 5 5 8 14 Voltage triggering SETTINGS SYSTEM SETUP PHASOR MEASUREMENT UNIT PHASOR MEASUREMENT UNIT 1 PMU 1 TRIGGERING PMU 1 VOLTAGE T...

Page 404: ...a nominal voltage value defined as the nominal secondary voltage times VT ratio The comparator applies a 1 hysteresis PMU 1 VOLT TRIGGER PKP TIME Use to filter out spurious conditions and avoid unnecessary triggering of the recorder PMU 1 VOLT TRIGGER DPO TIME Use to extend the trigger after the situation returns to normal This setting is of importance when using the recorder in the forced mode re...

Page 405: ... SETUP PHASOR MEASUREMENT UNIT PHASOR MEASUREMENT UNIT 1 PMU 1 TRIGGERING PMU 1 POWER TRIGGER This element responds to abnormal power Separate thresholds are provided for active reactive and apparent powers In terms of signaling its operation the element does not differentiate among the three types of power The trigger responds to the single phase and three phase power signals of the Phasor Measur...

Page 406: ...roduct of nominal secondary voltage the VT ratio and the nominal primary current For the three phase power 1 pu is three times that for a single phase power The comparator applies a 3 hysteresis PMU 1 POWER TRIGGER PKP TIME Use to filter out spurious conditions and avoid unnecessary triggering of the recorder PMU 1 POWER TRIGGER DPO TIME Use to extend the trigger after the situation returns to nor...

Page 407: ...ing SETTINGS SYSTEM SETUP PHASOR MEASUREMENT UNIT PHASOR MEASUREMENT UNIT 1 RECORDING PMU 1 PMU 1 FUNCTION This setting enables or disables the recorder for PMU 1 The rate is fixed at the reporting rate set within the aggregator that is Aggregator 1 PMU 1 NO OF TIMED RECORDS Specifies the number of timed records that are available for a given logical PMU 1 The length of each record is equal to the...

Page 408: ...and unique to avoid port number collisions PMU AGGREGATOR 1 PDC CONTROL The synchrophasor standard allows for user defined controls originating at the PDC to be executed on the PMU The control is accomplished via an extended command frame The relay decodes the first word of the extended field EXTFRAME to drive 16 dedicated FlexLogic operands Each aggregator supports 16 FlexLogic operands as shown ...

Page 409: ...hasor data concentrator asserts control bit 1 as received via the network as above AGTR1 PDC CNTRL 2 Phasor data concentrator asserts control bit 2 as received via the network as above AGTR1 PDC CNTRL 3 Phasor data concentrator asserts control bit 3 as received via the network as above AGTR1 PDC CNTRL 16 Phasor data concentrator asserts control bit 16 as received via the network as above AGTR2 PDC...

Page 410: ...na control bit R SV CB1 CLIENT CONTRL This setting determines if a client can write to the reserve bit When the assigned FlexLogic operand is a logic 1 state remote clients can write to both the reserve bit and the SvEna bit When the FlexLogic operand is a logic 0 state the remote client writes to the reserve bit the SvEna is rejected by the UR and a negative response with the appropriate Service ...

Page 411: ...tion multicast IP address that is entered in Standard IPV4 address format The valid range for IPv4 is from 224 0 0 0 to 239 255 255 255 The UR does not test the address entered R SV CB1 SECURITY This setting selects the level of security and authentication used as outlined in the following table and is in the form of an enumeration as per standard The range is 0 to 2 Table 5 22 Security 5 6 FlexLo...

Page 412: ...rcurrent element the two control input states are programmed in a FlexLogic equation This equation ANDs the two control inputs to produce a virtual output that is then selected when programming the phase time overcurrent to be used as a blocking input Virtual outputs can only be created by FlexLogic equations Traditionally protective relay logic has been relatively limited Any unusual applications...

Page 413: ...osed Current On Cont Op 1 Ion Current is flowing through the contact Voltage On Cont Op 1 VOn Voltage exists across the contact Voltage Off Cont Op 1 VOff Voltage does not exist across the contact Direct Input On DIRECT INPUT 1 On The direct input is presently in the ON state Element Analog Pickup PHASE TOC1 PKP The tested parameter is presently above the pickup setting of an element that responds...

Page 414: ...S 1 FAIL 87L DIFF GPS 2 FAIL 87L DIFF BLOCKED 87L DIFF PKP G 87L DIFF OP G At least one phase of current differential has operated Phase A of current differential has operated Phase B of current differential has operated Phase C of current differential has operated Direct transfer trip is keyed Direct transfer trip phase A has been received Direct transfer trip phase B has been received Direct tra...

Page 415: ...y undervoltage element has operated AUX UV2 to 3 Same set of operands as shown for AUX UV1 ELEMENT Breaker flashover BKR 1 FLSHOVR PKP A BKR 1 FLSHOVR PKP B BKR 1 FLSHOVR PKP C BKR 1 FLSHOVR PKP BKR 1 FLSHOVR OP A BKR 1 FLSHOVR OP B BKR 1 FLSHOVR OP C BKR 1 FLSHOVR OP BKR 1 FLSHOVR DPO A BKR 1 FLSHOVR DPO B BKR 1 FLSHOVR DPO C BKR 1 FLSHOVR DPO Breaker 1 flashover element phase A has picked up Bre...

Page 416: ...r 1 bad status is detected on any pole Breaker 1 is closed Breaker 1 is open Breaker 1 has discrepancy Breaker 1 trouble alarm Breaker 1 manual open Breaker 1 manual close Breaker 1 trip phase A command Breaker 1 trip phase B command Breaker 1 trip phase C command At least one pole of breaker 1 is open Only one pole of breaker 1 is open Breaker 1 is out of service Breaker 1 tagged so manual trip a...

Page 417: ...cheme has tripped all 3 phases Directional blocking scheme has operated ELEMENT Blocking 1 scheme DIR BLOCK1 TX INIT DIR BLOCK1 TX1 STOP DIR BLOCK1 TX2 STOP DIR BLOCK1 TX3 STOP DIR BLOCK1 TX4 STOP DIR BLOCK1 TRIP A DIR BLOCK1 TRIP B DIR BLOCK1 TRIP C DIR BLOCK1 TRIP 3P DIR BLOCK1 OP Directional blocking1 signal is initiated Directional blocking1 scheme de asserts transmit bit no 1 Directional bloc...

Page 418: ...of operands as shown for GROUND IOC 1 ELEMENT Ground time overcurrent GROUND TOC1 PKP GROUND TOC1 OP GROUND TOC1 DPO Ground time overcurrent 1 has picked up Ground time overcurrent 1 has operated Ground time overcurrent 1 has dropped out GROUND TOC2 to 6 Same set of operands as shown for GROUND TOC1 ELEMENT Hybrid POTT Hybrid permissive overreach transfer trip HYBRID POTT TX1 HYBRID POTT TX2 HYBRI...

Page 419: ...ELEMENT Neutral directional overcurrent NTRL DIR OC1 FWD NTRL DIR OC1 REV Neutral directional overcurrent 1 forward has operated Neutral directional overcurrent 1 reverse has operated NTRL DIR OC2 Same set of operands as shown for NTRL DIR OC1 ELEMENT Open pole detector OPEN POLE OP φA OPEN POLE OP φB OPEN POLE OP φC OPEN POLE BKR φA OP OPEN POLE BKR φB OP OPEN POLE BKR φC OP OPEN POLE BLK N OPEN ...

Page 420: ...neous overcurrent 1 has picked up Phase C of phase instantaneous overcurrent 1 has picked up Phase A of phase instantaneous overcurrent 1 has operated Phase B of phase instantaneous overcurrent 1 has operated Phase C of phase instantaneous overcurrent 1 has operated Phase A of phase instantaneous overcurrent 1 has dropped out Phase B of phase instantaneous overcurrent 1 has dropped out Phase C of ...

Page 421: ...unit 1 has operated Overpower trigger of phasor measurement unit 1 has operated Rate of change of frequency trigger of phasor measurement unit 1 has operated Abnormal voltage trigger of phasor measurement unit 1 has operated Phasor measurement unit 1 triggered no events or targets are generated by this operand ELEMENT Synchrophasor one shot PMU ONE SHOT EXPIRED PMU ONE SHOT OP PMU ONE SHOT PENDING...

Page 422: ...et of operands as shown for RESTD GND FT1 ELEMENT Selector switch SELECTOR 1 POS Y SELECTOR 1 BIT 0 SELECTOR 1 BIT 1 SELECTOR 1 BIT 2 SELECTOR 1 STP ALARM SELECTOR 1 BIT ALARM SELECTOR 1 ALARM SELECTOR 1 PWR ALARM Selector switch 1 is in Position Y mutually exclusive operands First bit of the 3 bit word encoding position of selector 1 Second bit of the 3 bit word encoding position of selector 1 Th...

Page 423: ...cking is not bypassed manually SWITCH 2 to 24 Same set of operands as shown for SWITCH 1 ELEMENT Synchrocheck SYNC1 DEAD S OP SYNC1 DEAD S DPO SYNC1 SYNC OP SYNC1 SYNC DPO SYNC1 CLS OP SYNC1 CLS DPO SYNC1 V1 ABOVE MIN SYNC1 V1 BELOW MAX SYNC1 V2 ABOVE MIN SYNC1 V2 BELOW MAX SYNC1 S CLOSE OP SYNC1 S CLOSE OP DPO SYNC1 S CLOSE ARMD Synchrocheck 1 dead source has operated Synchrocheck 1 dead source h...

Page 424: ...IOn Cont Op 72 IOn does not appear unless ordered does not appear unless ordered does not appear unless ordered INPUTS OUTPUTS Contact outputs voltage from detector on form A output only Cont Op 1 VOn Cont Op 2 VOn Cont Op 72 VOn does not appear unless ordered does not appear unless ordered does not appear unless ordered Cont Op 1 VOff Cont Op 2 VOff Cont Op 72 VOff does not appear unless ordered ...

Page 425: ...ent picks up and to turn Event Cause LED 1 on by default Asserted when a voltage element involved and to turn Event Cause LED 2 on by default Asserted when a current element involved and to turn Event Cause LED 3 on by default Asserted when a frequency element involved and to turn Event Cause LED 4 on by default Asserted when a composite element involved and to turn Event Cause LED 5 on by default...

Page 426: ...IL CLOCK UNSYNCHRONIZED DIRECT DEVICE OFF DIRECT RING BREAK EQUIPMENT MISMATCH FLEXLOGIC ERR TOKEN IRIG B FAILURE LATCHING OUT ERROR MAINTENANCE ALERT FIRST ETHERNET FAIL PROCESS BUS FAILURE PTP FAILURE RxGOOSE OFF RRTD COMM FAIL SECOND ETHERNET FAIL THIRD ETHERNET FAIL SNTP FAILURE SYSTEM EXCEPTION TEMP MONITOR UNIT NOT PROGRAMMED SETTING CHANGED Any of the major self test errors generated major ...

Page 427: ...n response to an edge on the input The output from a one shot is True positive for only one pass through the FlexLogic equation There is a maximum of 64 one shots NEGATIVE ONE SHOT One shot that responds to a negative going edge DUAL ONE SHOT One shot that responds to both the positive and negative going edges Logic gate NOT Logical NOT Operates on the previous parameter OR 2 OR 16 2 input OR gate...

Page 428: ... altered until this condition is satisfied Once done count the inputs to each gate to verify that the number of inputs does not exceed the FlexLogic limits which is unlikely but possible If the number of inputs is too high subdivide the inputs into multiple gates to produce an equivalent For example if 25 inputs to an AND gate are required connect Inputs 1 through 16 to AND 16 17 through 25 to AND...

Page 429: ...gic equations with outputs of virtual output 3 and virtual output 4 shown as follows Figure 5 99 Logic example with virtual outputs 2 Prepare a logic diagram for the equation to produce virtual output 3 as this output is used as an operand in the virtual output 4 equation create the equation for every output that is used as an operand first so that when these operands are required they already hav...

Page 430: ...edure outlined start with parameter 99 as follows 99 The final output of the equation is virtual output 3 which is created by the operator Virt Op n This parameter is therefore Virt Op 3 98 The gate preceding the output is an AND which in this case requires two inputs The operator for this gate is a 2 input AND so the parameter is AND 2 Note that FlexLogic rules require that the number of inputs t...

Page 431: ... is operand TIMER 2 Note that the settings required for the timer are established in the timer programming section 97 The operator preceding timer 2 is OR 2 a 3 input OR which is parameter OR 3 96 The lowest input to OR 2 is operand Cont Ip H1c On 95 The center input to OR 2 is operand TIMER 1 94 The input to timer 1 is operand Virt Op 3 On 93 The upper input to OR 2 is operand LATCH S R 92 There ...

Page 432: ...l Outputs that are used as inputs to operators are created before needed In cases where a lot of processing is required to perform logic this can be difficult to achieve but in most cases does not cause problems as all logic is calculated at least four times per power frequency cycle The possibility of a problem caused by sequential processing emphasizes the necessity to test the performance of Fl...

Page 433: ...e flag is never set to 1 Press the key when editing FlexLogic equations to quickly scan through the major parameter types 5 6 6 FlexLogic timers SETTINGS FLEXLOGIC FLEXLOGIC TIMERS FLEXLOGIC TIMER 1 32 There are 32 identical FlexLogic timers available These timers are used as operators for FlexLogic equations TIMER 1 TYPE Selects the time measurement unit TIMER 1 PICKUP DELAY Sets the time delay t...

Page 434: ...erating signal is higher than a threshold or lower than a threshold as per your choice FLEXELEMENT 1 INPUT MODE SIGNED Range SIGNED ABSOLUTE FLEXELEMENT 1 COMP MODE LEVEL Range LEVEL DELTA FLEXELEMENT 1 DIRECTION OVER Range OVER UNDER FLEXELEMENT 1 PICKUP 1 000 pu Range 90 000 to 90 000 pu in steps of 0 001 FLEXELEMENT 1 HYSTERESIS 3 0 Range 0 1 to 50 0 in steps of 0 1 FLEXELEMENT 1 dt UNIT Millis...

Page 435: ...d phase angle to build the effective operating signal The element responds directly to the differential signal if the FLEXELEMENT 1 INPUT MODE setting is set to Signed The element responds to the absolute value of the differential signal if this setting is set to Absolute Sample applications for the Absolute setting include monitoring the angular difference between two phasors with a symmetrical l...

Page 436: ...ON MANUAL FLEXLOGIC CHAPTER 5 SETTINGS 5 Figure 5 106 FlexElement direction pickup and hysteresis In conjunction with the FLEXELEMENT 1 INPUT MODE setting the element can be programmed to provide two extra characteristics as shown in the following figure ...

Page 437: ...ting signal and the pickup threshold can be negative facilitating applications such as reverse power alarm protection The FlexElement can be programmed to work with all analog actual values measured by the relay The FLEXELEMENT 1 PICKUP setting is entered in per unit values using the following definitions of the base units Table 5 27 FlexElement base units Unit Description 87L SIGNALS Local IA Mag...

Page 438: ... ϕBASE 360 degrees see the UR angle referencing convention POWER FACTOR PFBASE 1 00 RTDs BASE 100 C SENSITIVE DIR POWER Sns Dir Power PBASE maximum value of 3 VBASE IBASE for the IN and IN inputs of the sources configured for the sensitive power directional element s SOURCE CURRENT IBASE maximum nominal primary RMS value of the IN and IN inputs SOURCE ENERGY Positive and Negative Watthours Positiv...

Page 439: ...If asserted the specified FlexLogic operands sets Latch 1 LATCH 1 RESET If asserted the specified FlexLogic operand resets Latch 1 Figure 5 108 Non volatile latch operation table N 1 to 16 and logic LATCH 1 TYPE Reset Dominant Range Reset Dominant Set Dominant LATCH 1 SET Off Range FlexLogic operand LATCH 1 RESET Off Range FlexLogic operand LATCH 1 TARGET Self reset Range Self reset Latched Disabl...

Page 440: ...on to Elements section at the beginning of this chapter 5 7 2 Setting group 1 SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 Each of the six setting group menus is identical Setting group 1 the default active group is active automatically when no other group is active If the device incorrectly switches to group 1 after power cycling upgrade the firmware to version 7 31 or later to correct this issue ...

Page 441: ...SOURCE 4 None Range None SRC 1 SRC 2 SRC 3 SRC 4 CURRENT DIFF BLOCK Off Range FlexLogic operand CURRENT DIFF PICKUP 0 20 pu Range 0 10 to 4 00 pu in steps of 0 01 CURRENT DIFF CT TAP 1 1 00 Range 0 20 to 5 00 in steps of 0 01 CURRENT DIFF CT TAP 2 1 00 Range 0 20 to 5 00 in steps of 0 01 CURRENT DIFF RESTRAINT 1 30 Range 1 to 50 in steps of 1 CURRENT DIFF RESTRAINT 2 50 Range 1 to 70 in steps of 1...

Page 442: ...ings select the bias characteristic for the first and second slope respectively CURRENT DIFF BREAK PT This setting is used to select an intersection point between the two slopes INRUSH INHIBIT MODE This setting selects the mode for blocking differential protection during magnetizing inrush conditions Modern transformers can produce small second harmonic ratios during inrush conditions This can res...

Page 443: ...ial element Since this element is used to detect high resistive faults where fault currents are relatively low high speed operation is usually not critical This delay provides security against spurious neutral current during switch off transients and external fault clearing CURRENT DIFF DTT This setting enables and disables the sending of a direct transfer trip DTT by the current differential elem...

Page 444: ...5 220 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 109 Current differential logic ...

Page 445: ...perate quickly enough to pick up the STUB BUS OPERATE operand disable the local differential and send zero currents to the other terminal s If the bus minimum fault current is above five times the instantaneous overcurrent pickup tests have confirmed that the STUB BUS OPERATE operand always picks up correctly for a stub bus fault and prevents tripping of the remote terminal If minimum stub bus fau...

Page 446: ...AY 0 150 s Range 0 000 to 65 535 s in steps of 0 001 LINE END OPEN RESET DELAY 0 090 s Range 0 000 to 65 535 s in steps of 0 001 LINE PICKUP OV PKP DELAY 0 040 s Range 0 000 to 65 535 s in steps of 0 001 AR CO ORD BYPASS Enabled Range Disabled Enabled AR CO ORD PICKUP DELAY 0 045 s Range 0 000 to 65 535 s in steps of 0 001 AR CO ORD RESET DELAY 0 005 s Range 0 000 to 65 535 s in steps of 0 001 TER...

Page 447: ...ion functionality if external autoreclosure is employed Another zone 1 extension approach is to apply permanently an overreaching zone and reduce the reach when reclosing This philosophy can be programmed via the autoreclose scheme LINE PICKUP FUNCTION This setting enables and disables the line pickup feature LINE PICKUP SIGNAL SOURCE Selects the signal source for line pickup protection PHASE IOC ...

Page 448: ...11 Line pickup logic 5 7 5 Distance 5 7 5 1 Menu SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 DISTANCE DISTANCE DISTANCE SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 MEMORY DURATION 10 cycles Range 5 to 25 cycles in steps of 1 FORCE SELF POLAR Off Range FlexLogic operand FORCE MEM POLAR Off Range FlexLogic operand ...

Page 449: ...tions The distance zones can be forced to become self polarized through the FORCE SELF POLAR setting Any user selected condition any FlexLogic operand can be configured to force self polarization When the selected operand is asserted logic 1 the distance functions become self polarized regardless of other memory voltage logic conditions When the selected operand is de asserted logic 0 the distance...

Page 450: ...S DIST Z1 DIR Forward Range Forward Reverse Non directional PHS DIST Z1 SHAPE Mho Range Mho Quad PHS DIST Z1 XFMR VOL CONNECTION None Range None Dy1 Dy3 Dy5 Dy7 Dy9 Dy11 Yd1 Yd3 Yd5 Yd7 Yd9 Yd11 PHS DIST Z1 XFMR CUR CONNECTION None Range None Dy1 Dy3 Dy5 Dy7 Dy9 Dy11 Yd1 Yd3 Yd5 Yd7 Yd9 Yd11 PHS DIST Z1 REACH 2 00 Ω Range 0 02 to 500 00 ohms in steps of 0 01 PHS DIST Z1 RCA 85 Range 30 to 90 in st...

Page 451: ...dropout DPO FlexLogic operands or time delayed elements operate OP FlexLogic operands only zone 1 is intended for the instantaneous under reaching tripping mode PHS DIST Z1 DIR All phase distance zones are reversible The forward direction is defined by the PHS DIST Z1 RCA setting whereas the reverse direction is shifted 180 from that angle The non directional zone spans between the forward reach i...

Page 452: ...LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 113 Directional mho phase distance characteristic Figure 5 114 Non directional mho phase distance characteristic ...

Page 453: ...ROUPED ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 229 5 Figure 5 115 Directional quadrilateral phase distance characteristic Figure 5 116 Non directional quadrilateral phase distance characteristic ...

Page 454: ...5 230 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 117 Mho distance characteristic sample shapes ...

Page 455: ...ng In section a zone 1 is looking through a transformer from the delta into the wye winding Therefore the Z1 setting is set to Dy11 In section b Zone 3 is looking through a transformer from the wye into the delta winding Therefore the Z3 setting is set to Yd1 The zone is restricted by the potential point location of the VTs as illustrated in e PHS DIST Z1 XFMR CUR CONNECTION This setting specifies...

Page 456: ...80 to 85 of the line impedance reach setting even when zone 1 is disabled PHS DIST Z1 RCA This setting specifies the characteristic angle similar to the maximum torque angle in previous technologies of the phase distance characteristic for the forward and reverse applications In the non directional applications this setting defines the angle of the forward reach impedance The reverse reach impedan...

Page 457: ...racteristic figures The angular position of the blinder is adjustable with the use of the PHS DIST Z1 QUAD LFT BLD RCA setting This setting applies only to the quadrilateral characteristic and is set with consideration to the maximum load current PHS DIST Z1 QUAD LFT BLD RCA This setting defines the angular position of the left blinder of the quadrilateral characteristic see the Quadrilateral Dist...

Page 458: ...ce zone 2 OP logic For phase distance zone 2 there is a provision to start the zone timer with other distance zones or loop the pickup flag to avoid prolonging phase distance zone 2 operation when the fault evolves from one type to another or migrates from the initial zone to zone 2 Assign the required zones in the trip output function to accomplish this functionality ...

Page 459: ...CHAPTER 5 SETTINGS GROUPED ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 235 5 Figure 5 122 Phase distance zones 3 and higher OP logic Figure 5 123 Phase distance logic ...

Page 460: ...o 90 in steps of 1 GND DIST Z1 REV REACH 2 00 Ω Range 0 02 to 500 00 ohms in steps of 0 01 GND DIST Z1 REV REACH RCA 85 Range 30 to 90 in steps of 1 GND DIST Z1 POL CURRENT Zero seq Range Zero seq Neg seq GND DIST Z1 NON HOMOGEN ANG 0 0 Range 40 0 to 40 0 in steps of 0 1 GND DIST Z1 COMP LIMIT 90 Range 30 to 90 in steps of 1 GND DIST Z1 DIR RCA 85 Range 30 to 90 in steps of 1 GND DIST Z1 DIR COMP ...

Page 461: ...y for each of the zones except The SIGNAL SOURCE setting common for both phase and ground elements for all zones as entered under the SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 DISTANCE menu The MEMORY DURATION setting common for both phase and ground elements for all zones as entered under the SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 DISTANCE menu The common distance settings noted at the sta...

Page 462: ... DIST Z1 Z0 Z1 ANG This setting specifies the angle difference between the zero sequence and positive sequence impedance required for zero sequence compensation of the ground distance elements The entered value is the zero sequence impedance angle minus the positive sequence impedance angle This setting is available on a per zone basis enabling precise values for tapped non homologous and series c...

Page 463: ...GND DIST Z1 REV REACH RCA This setting defines the angle of the reverse reach impedance if the zone is set to non directional GND DIST Z1 DIR setting This setting does not apply when the zone direction is set to Forward or Reverse GND DIST Z1 POL CURRENT This setting applies only if the GND DIST Z1 SHAPE is set to Quad and controls the polarizing current used by the reactance comparator of the qua...

Page 464: ...teristic see the Quadrilateral Distance Characteristic figure GND DIST Z1 SUPV The ground distance elements are supervised by the magnitude of the neutral 3I_0 current Set the current supervision pickup to be less than the minimum 3I_0 current for the end of the zone fault taking into account the required fault resistance coverage to prevent maloperation due to VT fuse failure Settings less than 0...

Page 465: ...stance zone 2 OP scheme For ground distance zone 2 there is a provision to start the zone timer with the other distance zones or loop pickup flags to avoid prolonging ground distance zone 2 operation if the fault evolves from one type to another or migrates from zone 3 or 4 to zone 2 Assign the required zones in the trip output element to accomplish this functionality ...

Page 466: ...5 242 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 128 Ground distance zones 3 and higher OP scheme ...

Page 467: ...CHAPTER 5 SETTINGS GROUPED ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 243 5 Figure 5 129 Ground distance zone 1 pickup logic ...

Page 468: ...d operation of the ground element in a sound phase if the zone reach setting is increased to cover high resistance faults Ground distance zones 2 and higher use an additional ground directional supervision to enhance directional integrity The element s directional characteristic angle is used as a maximum torque angle together with a 90 limit angle The supervision is biased toward operation in ord...

Page 469: ...gic operand POWER SWING I2 SUPV 0 200 pu Range 0 050 to 30 000 pu in steps of 0 001 POWER SWING FWD REACH 50 00 Ω Range 0 10 to 500 00 ohms in steps of 0 01 POWER SWING QUAD FWD REACH MID 60 00 Ω Range 0 10 to 500 00 ohms in steps of 0 01 POWER SWING QUAD FWD REACH OUT 70 00 Ω Range 0 10 to 500 00 ohms in steps of 0 01 POWER SWING FWD RCA 75 Range 40 to 90 in steps of 1 POWER SWING REV REACH 50 00...

Page 470: ...ent protection elements respond differently to power swings If tripping is required for faults during power swing conditions some elements can be blocked permanently using the POWER SWING BLOCK operand and others can be blocked and dynamically unblocked upon fault detection using the POWER SWING UN BLOCK operand POWER SWING INNER LIMIT ANGLE 60 Range 40 to 140 in steps of 1 POWER SWING OUTER RGT B...

Page 471: ...the impedance stays within the outer characteristic If afterwards at any time given the impedance stays within the outer characteristic the locus enters the middle characteristic but stays outside the inner characteristic for a period of time defined as POWER SWING PICKUP DELAY 2 latch 2 is set as long as the impedance stays inside the outer characteristic If afterwards at any time given the imped...

Page 472: ...LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 132 Power swing detect mho operating characteristics Figure 5 133 Effects of blinders on the mho characteristics ...

Page 473: ...g during power swing conditions This includes both three phase and single pole open conditions POWER SWING INCOMING indicates an unstable power swing with an incoming locus the locus enters the inner characteristic POWER SWING OUTGOING indicates an unstable power swing with an outgoing locus the locus leaving the outer characteristic This operand can be used to count unstable swings and take certa...

Page 474: ...hape setting is Mho POWER SWING QUAD FWD REACH OUT This setting specifies the forward reach of the outer quadrilateral characteristic The angle of this reach impedance is specified by the POWER SWING FWD RCA setting The setting is not used if the shape setting is Mho POWER SWING FWD RCA This setting specifies the angle of the forward reach impedance for the mho characteristics angles of all blinde...

Page 475: ...urity for the power swing blocking action POWER SWING PICKUP DELAY 2 Controls the out of step tripping function in the three step mode only This timer defines the interval the impedance locus must spend between the middle and inner characteristics before the second step of the out of step tripping sequence is completed This time delay must be set shorter than the time required for the impedance lo...

Page 476: ...5 252 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 135 Power swing detect logic Sheet 1 of 3 ...

Page 477: ...CHAPTER 5 SETTINGS GROUPED ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 253 5 Figure 5 136 Power swing detect logic Sheet 2 of 3 Figure 5 137 Power swing detect logic Sheet 3 of 3 ...

Page 478: ... figure shows an effect of the load encroachment characteristics used to block the quadrilateral distance element LOAD ENCROACHMENT LOAD ENCROACHMENT FUNCTION Disabled Range Disabled Enabled LOAD ENCROACHMENT SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 LOAD ENCROACHMENT MIN VOLT 0 250 pu Range 0 004 to 3 000 pu in steps of 0 001 LOAD ENCROACHMENT REACH 1 00 Ω Range 0 02 to 250 00 ohms in steps of 0...

Page 479: ...he SYSTEM SETUP AC INPUTS VOLTAGE BANK X5 PHASE VT SECONDARY setting is the per unit base for this setting LOAD ENCROACHMENT REACH This setting specifies the resistive reach of the element as shown in the Load Encroachment Characteristic diagram Enter this setting in secondary ohms and calculate it as the positive sequence resistance seen by the relay under maximum load conditions and unity power ...

Page 480: ... variable indicates that the energy capacity has reached 100 a time overcurrent element operates If less than 100 energy capacity is accumulated in this variable and the current falls below the dropout threshold of 97 to 98 of the pickup value the variable must be reduced Two methods of this resetting operation are available Instantaneous and Timed The Instantaneous selection is intended for appli...

Page 481: ... 0 813 4 0 90 727 38 087 14 587 8 007 5 187 3 710 2 837 2 277 1 897 1 626 6 0 136 090 57 130 21 880 12 010 7 780 5 564 4 255 3 416 2 845 2 439 8 0 181 454 76 174 29 174 16 014 10 374 7 419 5 674 4 555 3 794 3 252 10 0 226 817 95 217 36 467 20 017 12 967 9 274 7 092 5 693 4 742 4 065 IEEE Very Inverse 0 5 8 090 3 514 1 471 0 899 0 654 0 526 0 450 0 401 0 368 0 345 1 0 16 179 7 028 2 942 1 798 1 308...

Page 482: ...71 IEC Curve B 0 05 1 350 0 675 0 338 0 225 0 169 0 135 0 113 0 096 0 084 0 075 0 10 2 700 1 350 0 675 0 450 0 338 0 270 0 225 0 193 0 169 0 150 0 20 5 400 2 700 1 350 0 900 0 675 0 540 0 450 0 386 0 338 0 300 0 40 10 800 5 400 2 700 1 800 1 350 1 080 0 900 0 771 0 675 0 600 0 60 16 200 8 100 4 050 2 700 2 025 1 620 1 350 1 157 1 013 0 900 0 80 21 600 10 800 5 400 3 600 2 700 2 160 1 800 1 543 1 3...

Page 483: ... IAC Extremely Inverse 0 5 1 699 0 749 0 303 0 178 0 123 0 093 0 074 0 062 0 053 0 046 1 0 3 398 1 498 0 606 0 356 0 246 0 186 0 149 0 124 0 106 0 093 2 0 6 796 2 997 1 212 0 711 0 491 0 372 0 298 0 248 0 212 0 185 4 0 13 591 5 993 2 423 1 422 0 983 0 744 0 595 0 495 0 424 0 370 6 0 20 387 8 990 3 635 2 133 1 474 1 115 0 893 0 743 0 636 0 556 8 0 27 183 11 987 4 846 2 844 1 966 1 487 1 191 0 991 0...

Page 484: ...7 0 026 0 026 0 025 0 025 1 0 0 143 0 095 0 070 0 061 0 057 0 054 0 052 0 051 0 050 0 049 2 0 0 286 0 190 0 140 0 123 0 114 0 108 0 105 0 102 0 100 0 099 4 0 0 573 0 379 0 279 0 245 0 228 0 217 0 210 0 204 0 200 0 197 6 0 0 859 0 569 0 419 0 368 0 341 0 325 0 314 0 307 0 301 0 296 8 0 1 145 0 759 0 559 0 490 0 455 0 434 0 419 0 409 0 401 0 394 10 0 1 431 0 948 0 699 0 613 0 569 0 542 0 524 0 511 0...

Page 485: ... instantaneous to 600 00 seconds in steps of 10 ms The definite time curve shapes are defined as follows Eq 5 21 Eq 5 22 where T Operate Time in seconds TDM Multiplier setting I Input Current Ipickup Pickup Current setting TRESET Reset Time in seconds assuming energy capacity is 100 and RESET Timed Recloser curves The L90 uses the FlexCurve feature to facilitate programming of 41 recloser curves S...

Page 486: ...tage restraint characteristic curve see the figure the pickup level is calculated as Mvr times the PHASE TOC1 PICKUP setting If the voltage restraint feature is disabled the pickup level always remains at the setting value Figure 5 141 Phase time overcurrent voltage restraint characteristic FUNCTION This setting enables and disables the phase time overcurrent protection element SIGNAL SOURCE Selec...

Page 487: ...TRAINT Enables and disables the phase time overcurrent voltage restraint feature BLOCK A Assertion of the operand assigned to this setting blocks phase A of the phase time overcurrent element EVENTS Enables and disables the logging of phase time overcurrent events in the sequence of events recorder Figure 5 142 Phase time overcurrent 1 logic 5 7 8 4 Phase instantaneous overcurrent ANSI 50P IEC PIO...

Page 488: ...nstantaneous overcurrent element between the operate output state and the return to logic 0 after the input passes outside the defined pickup range This setting is used to ensure that the relay output contacts are closed long enough to ensure reception by downstream equipment BLOCK A Assertion of the operand assigned to this setting block s phase A of the phase instantaneous overcurrent element EV...

Page 489: ... CTs and the line line voltage from the VTs based on the 90 or quadrature connection If there is a requirement to supervise overcurrent elements for flows in opposite directions such as can happen through a bus tie breaker two phase directional elements should be programmed with opposite element characteristic angle ECA settings PHASE DIR 1 ECA 30 Range 0 to 359 in steps of 1 PHASE DIR POL V1 THRE...

Page 490: ...res In all cases directional blocking is permitted to resume when the polarizing voltage becomes greater than the polarizing voltage threshold Settings PHASE DIR 1 FUNCTION This setting enables and disables the phase directional overcurrent protection element PHASE DIR 1 SIGNAL SOURCE This setting is used to select the source for the operating and polarizing signals The operating current for the p...

Page 491: ...ponds to the forward load current In the case of a following reverse fault the element needs some time in the order of 8 ms to establish a blocking signal Some protection elements such as instantaneous overcurrent respond to reverse faults before the blocking signal is established Therefore a coordination time of at least 10 ms must be added to all the instantaneous protection elements under the s...

Page 492: ...e L90 Inputs can be selected as fundamental phasor magnitudes or total waveform RMS magnitudes as required by the application NEUTRAL TOC1 PICKUP This setting specifies the neutral time overcurrent pickup level in per unit values NEUTRAL TOC1 CURVE This setting selects the inverse time overcurrent curve style NEUTRAL TOC1 TD MULTIPLIER This setting specifies a multiple of the base curve shape spec...

Page 493: ...rformance A small portion 6 25 of the positive sequence current magnitude is subtracted from the zero sequence current magnitude when forming the operating quantity of the element as follows Iop 3 x I_0 K x I_1 where K 1 16 Eq 5 23 The positive sequence restraint allows for more sensitive settings by counterbalancing spurious zero sequence currents resulting from System unbalances under heavy load...

Page 494: ...rent element between the operate output state and the return to logic 0 after the input passes outside the defined pickup range This setting is used to ensure that the relay output contacts are closed long enough to ensure reception by downstream equipment a NEUTRAL IOC1 BLOCK Assertion of the operand assigned to this setting blocks operation of the neutral instantaneous overcurrent element NEUTRA...

Page 495: ...ay the test currents are injected into the relay single phase injection Iop 1 K Iinjected three phase pure zero sequence injection Iop 3 Iinjected The positive sequence restraint is removed for low currents If the positive sequence current is below 0 8 pu the restraint is removed by changing the constant K to zero This facilitates better response to high resistance faults when the unbalance is ver...

Page 496: ...rd indication is delayed by 1 5 of a power system cycle The element is designed to emulate an electromechanical directional device Larger operating and polarizing signals results in faster directional discrimination bringing more security to the element operation The forward looking function is designed to be more secure as compared to the reverse looking function and therefore is to be used for t...

Page 497: ...en offset impedance is applied and zero sequence current is above 0 2 pu compensated zero sequence voltage V_0 Z_offset x I_0 has to be above the display voltage cut off level in order to discriminate fault direction otherwise when zero sequence current is less than 0 2 pu V_0 is then used as the polarizing signal If the polarizing signal is invalid neither forward nor reverse indication is given ...

Page 498: ...is Measured IG then the NEUTRAL DIR OC1 POLARIZING setting must be Voltage as it is not possible to use the ground current as an operating and polarizing signal simultaneously IG current has to be above 0 05 ps to be used as operate quantity NEUTRAL DIR OC1 POS SEQ RESTRAINT This setting controls the amount of the positive sequence restraint Set it to 0 063 for backward compatibility with firmware...

Page 499: ... WATTMETRIC WATTMETRIC GROUND FAULT 1 2 WATTMETRIC GROUND FAULT 1 WATTMETRIC GND FLT 1 FUNCTION Disabled Range Disabled Enabled WATTMETRIC GND FLT 1 SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 WATTMETRIC GND FLT 1 VOLT Calculated VN Range Calculated VN Measured VX WATTMETRIC GND FLT 1 OV PKP 0 20 pu Range 0 02 to 3 00 pu in steps of 0 01 WATTMETRIC GND FLT 1 CURR Calculated IN Range Calculated IN M...

Page 500: ...ternally supplied voltage via the auxiliary voltage channel 1 pu is the nominal voltage of this channel as per VT bank settings When using internally calculated neutral voltage 1 pu is the nominal phase to ground voltage as per the VT bank settings WATTMETRIC GND FLT 1 CURR The element responds to the neutral current that is three times zero sequence current either calculated internally from the p...

Page 501: ...e curve selection is set as Definite Time the element operates after this security time delay If the curve selection is Inverse or one of the FlexCurves the element uses both the definite and inverse time timers simultaneously The definite time timer specified by this setting is used and when expires it releases the inverse time timer for operation torque control WATTMETRIC GND FLT 1 CURVE Choose ...

Page 502: ...GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 150 Wattmetric characteristic angle response WATTMETRIC GND FLT 1 MULTIPLIER This setting is applicable if the WATTMETRIC GND FLT 1 CURVE is set to Inverse and defines the multiplier factor for the inverse time delay ...

Page 503: ...E CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 279 5 Figure 5 151 Wattmetric zero sequence directional logic 5 7 11 Ground current 5 7 11 1 Menu SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 GROUND CURRENT GROUND CURRENT GROUND TOC1 See below ...

Page 504: ...g selects the signal source for the ground time overcurrent protection element GROUND TOC1 INPUT This setting selects how ground current input quantities are interpreted by the L90 Inputs can be selected as fundamental phasor magnitudes or total waveform RMS magnitudes as required by the application GROUND TOC1 PICKUP This setting specifies the ground time overcurrent pickup level in per unit valu...

Page 505: ...igure 5 152 Ground TOC1 logic 5 7 11 3 Ground instantaneous overcurrent ANSI 50G IEC PIOC SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 GROUND CURRENT GROUND IOC1 12 The ground instantaneous overcurrent element can be used as an instantaneous element with no intentional delay or as a definite time element The ground current input is the quantity measured by the ground input CT and is the fundamental...

Page 506: ...een the primary windings and the percentage of shorted turns on the secondary Therefore the resultant differential currents can be below the slope threshold of the main differential element and the fault can go undetected Application of the restricted ground fault protection extends the coverage towards the neutral point see the following figure These elements measure the current that is connected...

Page 507: ...ential stability problems An external phase to phase fault is an ultimate case Ideally there is neither ground IG nor neutral IN IA IB IC current present If one or more of the phase CTs saturate a spurious neutral current is seen by the relay This is similar to a single infeed situation and can be mistaken for an internal fault Similar difficulties occur in a breaker and a half application of the ...

Page 508: ...g normal operation that is two cycles after the winding has been energized The lower multiplier is used to ensure better sensitivity when energizing a faulty winding The positive sequence component of the restraining signal IR1 is meant to provide restraint during symmetrical conditions either symmetrical faults or load and is calculated according to the following algorithm 1 If I_1 2 pu of phase ...

Page 509: ...training signal is twice the fault current This gives extra margin if the phase or neutral CT saturates Example 2 External high current SLG fault Given the following inputs IA 10 pu 0 IB 0 IC 0 and IG 10 pu 180 The relay calculates the following values Igd 0 and Igr 20 pu Example 3 External high current three phase symmetrical fault Given the following inputs IA 10 pu 0 IB 10 pu 120 IC 10 pu 120 a...

Page 510: ...IA 10 pu 0 IB 0 pu IC 0 pu and IG 0 pu The relay calculates the following values I_0 3 3 pu 0 I_2 3 3 pu 0 and I_1 3 3 pu 0 Igd abs 3 3 3 0 0 10 pu IR0 abs 3 3 3 0 0 10 pu IR2 3 3 3 10 pu IR1 3 3 33 3 33 0 pu and Igr 10 pu The differential current is 100 of the restraining current 5 7 12 Negative sequence current 5 7 12 1 Menu SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 NEGATIVE SEQUENCE CURRENT T...

Page 511: ...ly Figure 5 157 Negative sequence TOC1 logic 5 7 12 3 Negative sequence instantaneous overcurrent ANSI 50Q IEC PIOC SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 NEGATIVE SEQUENCE CURRENT NEG SEQ OC1 2 NEG SEQ TOC1 PICKUP 1 000 pu Range 0 020 to 30 000 pu in steps of 0 001 NEG SEQ TOC1 CURVE IEEE Mod Inv Range see Overcurrent Curve Types table NEG SEQ TOC1 TD MULTIPLIER 1 00 Range 0 00 to 600 00 in ...

Page 512: ...se faults Fault inception and switch off transients during three phase faults The positive sequence restraint must be considered when testing for pickup accuracy and response time multiple of pickup The operating quantity depends on how the test currents are injected into the relay single phase injection Iop 0 2917 x Iinjected three phase injection opposite rotation Iop Iinjected Figure 5 158 Nega...

Page 513: ...be considered when testing for pickup accuracy and response time multiple of pickup The positive sequence restraint is removed for low currents If the positive sequence current is less than 0 8 pu then the restraint is removed by changing the constant K to zero This results in better response to high resistance faults when the unbalance is very small and there is no danger of excessive CT errors s...

Page 514: ...teristics for a phase A to ground fault with settings of ECA 75 element characteristic angle centerline of operating characteristic FWD LA 80 forward limit angle the angular limit with the ECA for operation REV LA 80 reverse limit angle the angular limit with the ECA for operation The element incorporates a current reversal logic if the reverse direction is indicated for at least 1 25 of a power s...

Page 515: ...overcurrent function as inter circuit mutual effects are minimized NEG SEQ DIR OC1 POS SEQ RESTRAINT Controls the positive sequence restraint Set it to 0 063 in Zero Sequence mode or 0 125 in Neg Sequence mode for backward compatibility with revisions 3 40 and earlier Set it to zero to remove the restraint Set it higher if large system unbalances or poor CT performance are expected NEG SEQ DIR OC1...

Page 516: ...ge Disabled Enabled BF1 MODE 3 Pole Range 3 Pole 1 Pole BF1 SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 BF1 USE AMP SUPV Yes Range Yes No BF1 USE SEAL IN Yes Range Yes No BF1 3 POLE INITIATE Off Range FlexLogic operand BF1 BLOCK Off Range FlexLogic operand BF1 RETRIP PICKUP DELAY 0 033 s Range 0 000 to 65 535 s in steps of 0 001 BF1 PH AMP SUPV PICKUP 1 050 pu Range 0 020 to 30 000 pu in steps of 0...

Page 517: ...001 BF1 N AMP LOSET PICKUP 1 050 pu Range 0 020 to 30 000 pu in steps of 0 001 BF1 LOSET TIME DELAY 0 000 s Range 0 000 to 65 535 s in steps of 0 001 BF1 TRIP DROPOUT DELAY 0 000 s Range 0 000 to 65 535 s in steps of 0 001 BF1 TARGET Self Reset Range Self reset Latched Disabled BF1 EVENTS Disabled Range Disabled Enabled BF1 PH A INITIATE Off Range FlexLogic operand Valid only for 1 Pole breaker fa...

Page 518: ... half or ring bus configurations where the first breaker closes into a fault the protection trips and attempts to initiate breaker failure for the second breaker which is in the process of closing but does not yet have current flowing through it When the scheme is initiated it sends a trip signal after a pickup delay to the breaker initially signaled to trip this feature is usually described as re...

Page 519: ...e schemes are FlexLogic operands that report on the operation of portions of the scheme FlexLogic operand used to re trip the protected breaker FlexLogic operands that initiate tripping required to clear the faulted zone The trip output can be sealed in for an adjustable period Target message indicating a failed breaker has been declared Illumination of the front panel Trip LED and the Phase A B o...

Page 520: ...relays this time is not significant In L90 relays which use a Fourier transform the calculated current magnitude ramps down to zero one power frequency cycle after the current is interrupted and this lag needs to be included in the overall margin duration as it occurs after current interruption The Breaker Failure Main Path Sequence figure that follows shows a margin of two cycles this interval is...

Page 521: ...eaker and the phase A B or C portion of the scheme accordingly This setting is only valid for single pole breaker failure schemes BF1 BKR POS1 φB BF1 BKR POS 1 φC These settings select the FlexLogic operand to represents the protected breaker early type auxiliary switch contact on poles B or C accordingly This contact is normally a non multiplied Form A contact The contact can even be adjusted to ...

Page 522: ...5 298 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 163 Single pole breaker failure initiate logic ...

Page 523: ...CHAPTER 5 SETTINGS GROUPED ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 299 5 Figure 5 164 Single pole breaker failure timers logic ...

Page 524: ...5 300 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 165 Three pole breaker failure initiate logic ...

Page 525: ...CHAPTER 5 SETTINGS GROUPED ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 301 5 Figure 5 166 Three pole breaker failure timers logic ...

Page 526: ...voltage setting The undervoltage feature can also be used to block the functioning of other elements through the block feature of those elements Source transfer schemes In the event of an undervoltage a transfer signal can be generated to transfer a load from its normal source to a standby or emergency power source The undervoltage elements can be programmed to have a definite time delay character...

Page 527: ...etting 5 7 14 2 Phase undervoltage ANSI 27P IEC PTUV SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 VOLTAGE ELEMENTS PHASE UNDERVOLTAGE1 3 PHASE UNDERVOLTAGE1 PHASE UV1 FUNCTION Disabled Range Disabled Enabled PHASE UV1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 PHASE UV1 MODE Phase to Ground Range Phase to Ground Phase to Phase PHASE UV1 PICKUP 1 000 pu Range 0 004 to 3 000 pu in steps of 0 0...

Page 528: ... dead source to be considered a fault condition Figure 5 168 Phase undervoltage1 logic 5 7 14 3 Phase overvoltage ANSI 59P IEC PTOV SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 VOLTAGE ELEMENTS PHASE OVERVOLTAGE1 3 PHASE UV1 TARGET Self reset Range Self reset Latched Disabled PHASE UV1 EVENTS Disabled Range Disabled Enabled PHASE OVERVOLTAGE1 PHASE OV1 FUNCTION Disabled Range Disabled Enabled PHASE...

Page 529: ...V SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 VOLTAGE ELEMENTS NEUTRAL OV1 3 If the source VT is wye connected then the phase overvoltage pickup condition is V x Pickup for VAB VBC and VCA NEUTRAL OV1 NEUTRAL OV1 FUNCTION Disabled Range Disabled Enabled NEUTRAL OV1 SIGNAL SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 NEUTRAL OV1 PICKUP 0 300 pu Range 0 004 to 3 000 pu in steps of 0 001 NEUTRAL OV1 CU...

Page 530: ...n setting this element This function requires the VTs to be wye connected Figure 5 170 Neutral overvoltage1 logic 5 7 14 5 Auxiliary undervoltage ANSI 27X IEC PTUV SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 VOLTAGE ELEMENTS AUXILIARY UV1 3 The L90 contains one auxiliary undervoltage element for each VT bank This element monitors undervoltage conditions of the auxiliary voltage The AUX UV1 PICKUP ...

Page 531: ...ING GROUP 1 6 VOLTAGE ELEMENTS AUXILIARY OV1 2 The L90 contains one auxiliary overvoltage element for each VT bank This element is intended for monitoring overvoltage conditions of the auxiliary voltage The nominal secondary voltage of the auxiliary voltage channel entered under SYSTEM SETUP AC INPUTS VOLTAGE BANK X5 AUXILIARY VT X5 SECONDARY is the per unit pu base used when setting the pickup le...

Page 532: ...follows 1 If the phase voltage inputs defined in the source menu are used for V Hz operation then 1 pu is the selected SYSTEM SETUP AC INPUTS VOLTAGE BANK N PHASE VT N SECONDARY setting divided by the divided by the SYSTEM SETUP POWER SYSTEM NOMINAL FREQUENCY setting VOLTS HZ 1 VOLTS HZ 1 FUNCTION Disabled Range Disabled Enabled VOLTS HZ 1 SOURCE SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 VOLTS HZ 1 VOLT...

Page 533: ...INAL FREQUENCY setting 4 If V Hz source is configured with both phase and auxiliary voltages the maximum phase among the three voltage channels at any given point in time is the input voltage signal for element operation and therefore the per unit value is calculated as described in Step 1 If the measured voltage of all three phase voltages is 0 than the per unit value becomes automatically 0 rega...

Page 534: ...tz pickup setpoint pu The figure shows the volts hertz inverse A curves Figure 5 174 Volts per hertz curves inverse curve A Inverse curve B The curve for the Volts Hertz Inverse Curve B shape is derived from the formula Eq 5 38 where T Operating Time TDM Time Delay Multiplier delay in sec V fundamental RMS value of voltage pu F frequency of voltage signal pu Pickup volts per hertz pickup setpoint ...

Page 535: ...erse curve B Inverse curve C The curve for the Volts Hertz Inverse Curve C shape is derived from the formula Eq 5 39 where T Operating Time TDM Time Delay Multiplier delay in sec V fundamental RMS value of voltage pu F frequency of voltage signal pu Pickup volts per hertz pickup setpoint pu The figure shows the volts hertz inverse C curves ...

Page 536: ... MAG 2 00 ohm Range 0 00 to 500 00 ohms in steps of 0 01 COMPENSATED OV Zc ANG 90 Range 30 to 90 in steps of 1 COMPENSATED OV I_1max 0 20 pu Range 0 01 to 1 00 pu in steps of 0 01 COMPENSATED OV STG1 PKP 1 300 pu Range 0 250 to 3 000 pu in steps of 0 01 COMPENSATED OV STG1 DELAY 1 00 sec Range 0 00 to 600 00 seconds in steps of 0 01 COMPENSATED OV STG2 PKP 1 300 pu Range 0 250 to 3 000 pu in steps...

Page 537: ...ere V_1 is the positive sequence voltage phasor quantity in secondary volts measured at the local terminal I_1 is the positive sequence current phasor quantity in secondary amps measured at the local terminal Vnominal is the phase VT secondary setting in the case of wye VTs and the phase VT secondary setting divided by in the case of delta VTs ZC_mag and ZC_ang represent an impedance between the l...

Page 538: ...ich a remote overvoltage is anticipated COMPENSATED OV STG1 PKP COMPENSATED OV STG2 PKP COMPENSATED OV STG3 PKP These settings specify the pickup level for each of the three stages If any stage is set with no intentional time delay then set the pickup setting 15 above the anticipated steady state overvoltage to prevent an operation during line energization A stage that is not used can be set to it...

Page 539: ...VB DVC The adaptive level detector operates as follows When the absolute level increases above 0 12 pu for I_0 or I_2 the adaptive level detector output is active and the next highest threshold level is increased eight cycles later from 0 12 to 0 24 pu in steps of 0 02 pu If the level exceeds 0 24 pu the current adaptive level detector setting remains at 0 24 pu and the output remains active as we...

Page 540: ...ogic operand resets DD SEAL IN BY 87LG Used to seal in the disturbance detector output 50DD SV 87LG especially for the 87LG element whenever the 50DD SV might reset before 87LG time delay elapses 50DD SV 87LG is maintained until the 87L DIFF PKP G operand resets DD VOLTAGE SUPV Used to enable the voltage based disturbance detector for such applications as the weak condition exists at one terminal ...

Page 541: ...CHAPTER 5 SETTINGS GROUPED ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 317 5 Figure 5 180 Disturbance detector logic ...

Page 542: ...e open pole detector provides forcing of three pole tripping for sequential faults and close onto fault if wanted The open pole detector feature must be employed and adequately programmed for proper operation of this feature The 87L TRIP 1P OP and 87L TRIP 3P OP operands are provided to initiate single pole or three pole autoreclosing 87L TRIP FUNCTION This setting is used to enable or disable the...

Page 543: ...utoreclosure counter if for example the second trip is required to be a three pole signal Likewise any operand representing a change in the power system configuration can be applied 87L TRIP SEAL IN Enables disables seal in of the trip signal by measurement of the current flowing If the single pole trip mode is selected and the Trip Out element is applied set this setting to Disabled 87L TRIP SEAL...

Page 544: ...5 320 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL GROUPED ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 181 87L trip logic ...

Page 545: ...owing condition P cos θ Q sin θ SMIN Eq 5 42 where P and Q are active and reactive powers as measured per the UR metering convention θ is a sum of the element characteristic DIR POWER 1 RCA and calibration DIR POWER 1 CALIBRATION angles SMIN is the minimum operating power The operating quantity is displayed in the ACTUAL VALUES METERING SENSITIVE DIRECTIONAL POWER 1 2 actual value The element has ...

Page 546: ...aking the characteristic angle adjustable and providing for both negative and positive values of the minimum operating power a variety of operating characteristics can be achieved as presented in the following figure For example section a in the figure shows settings for reverse power while section b shows settings for low forward power applications ...

Page 547: ...overpower underpower and so on Together with a precise calibration angle it allows compensation for any CT and VT angular errors to permit more sensitive settings It allows for required direction in situations when the voltage signal is taken from behind a delta wye connected power transformer and the phase angle compensation is required For example the active overpower characteristic is achieved ...

Page 548: ...nge of operating characteristics This setting applies to three phase power and is entered in per unit pu values The base quantity is 3 x VT pu base x CT pu base For example a setting of 2 for a 200 MW machine is 0 02 200 MW 4 MW If 13 8kV is line voltage and 10 kA is a primary CT current the source pu quantity is 239 MVA and thus SMIN needs to be set at 4 MW 239 MVA 0 0167 pu 0 017 pu If the rever...

Page 549: ...te type operands are displayed and can be assigned to a trip bus If more than one operate type operand is required it can be assigned directly from the trip bus menu Figure 5 185 Trip bus fields in the protection summary The following settings are available TRIP BUS 1 BLOCK The trip bus output is blocked when the operand assigned to this setting is asserted TRIP BUS 1 PICKUP DELAY This setting spe...

Page 550: ...r user acknowledgement of the relay response is required TRIP BUS 1 RESET The trip bus output is reset when the operand assigned to this setting is asserted Note that the RESET OP operand is pre wired to the reset gate of the latch As such a reset command from the front panel interface or via communications resets the trip bus output Figure 5 186 Trip bus logic 5 8 3 Setting groups SETTINGS CONTRO...

Page 551: ...6 NAME Allows the user to assign a name to each of the six settings groups Once programmed this name appears on the second line of the GROUPED ELEMENTS SETTING GROUP 1 6 menu display The relay can be set up via a FlexLogic equation to receive requests to activate or de activate a particular non default settings group The following FlexLogic equation see the following figure illustrates requests vi...

Page 552: ...being out of range A selector switch runs every two power cycles SELECTOR 1 FULL RANGE This setting defines the upper position of the selector When stepping up through available positions of the selector the upper position wraps up to the lower position position 1 When using a direct three bit control word for programming the selector to a desired position the change would take place only if the c...

Page 553: ...cknowledging signal If the acknowledging signal does not appear within a pre defined period of time the selector does not accept the change and an alarm is established by setting the SELECTOR STP ALARM output FlexLogic operand for three seconds SELECTOR 1 ACK This setting specifies an acknowledging input for the stepping up control input The pre selected position is applied on the rising edge of t...

Page 554: ... and activates SELECTOR 1 PWR ALARM After two power cycles expire the selector synchronizes to the position dictated by the three bit control input This operation does not wait for time out or the acknowledging input When the synchronization attempt is unsuccessful that is the three bit input is not available 0 0 0 or out of range then the selector switch output is set to position 0 no output oper...

Page 555: ...CHAPTER 5 SETTINGS CONTROL ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 331 5 Figure 5 188 Time out mode ...

Page 556: ...oups are to be controlled from both user programmable pushbutton 1 and from an external device via contact inputs 1 through 3 The active setting group is to be available as an encoded three bit word to the external device and SCADA via output contacts 1 through 3 The pre selected setting group is to be applied automatically after five seconds of inactivity of the control inputs When the relay powe...

Page 557: ...NGE 4 SELECTOR 1 STEP UP MODE Time out SELECTOR 1 TIME OUT 5 0 s SELECTOR 1 STEP UP PUSHBUTTON 1 ON SELECTOR 1 ACK Off SELECTOR 1 3BIT A0 CONT IP 1 ON SELECTOR 1 3BIT A1 CONT IP 2 ON SELECTOR 1 3BIT A2 CONT IP 3 ON SELECTOR 1 3BIT MODE Time out SELECTOR 1 3BIT ACK Off SELECTOR 1 POWER UP MODE Synchronize Now assign the contact output operation assume the H6E module to the selector switch element b...

Page 558: ...IP MODE Disabled Range Disabled 3 Pole Only 3 Pole 1 Pole TRIP 3 POLE INPUT1 Off Range FlexLogic operand TRIP 3 POLE INPUT6 Off Range FlexLogic operand TRIP 1 POLE INPUT1 Off Range FlexLogic operand TRIP 1 POLE INPUT6 Off Range FlexLogic operand TRIP RECLOSE INPUT1 Off Range FlexLogic operand TRIP RECLOSE INPUT6 Off Range FlexLogic operand TRIP SEAL IN DELAY 0 000 s Range 0 to 65 535 s in steps of...

Page 559: ...puts to initiate three pole tripping the recloser and breaker failure elements Collect inputs to initiate single pole tripping the recloser and breaker failure elements Assign a higher priority to pilot aided scheme outputs than to exclusively local inputs TRIP RESET CBaux OR Custom Range Pole Curr OR Custom CBaux OR Custom Custom START TMR Z2PH Inp1 Off Range FlexLogic operand START TMR Z2PH Inp2...

Page 560: ... the operands for the faulted phase are asserted TRIP 3 POLE INPUT1 to TRIP 3 POLE INPUT6 These settings are used to select an operand representing a fault condition that is not wanted to initiate a single pole operation for example phase undervoltage Use a FlexLogic OR gate if more than six inputs are required TRIP 1 POLE INPUT1 to TRIP 1 POLE INPUT6 These settings are used to select an operand r...

Page 561: ...igned to cause single pole tripping to operate If for example it is intended that distance zone 2 with a time delay of 0 5 seconds causes a single pole trip then this setting has to be at least 0 6 seconds PH SELECTOR RESET This setting selects an operand to reset the Phase Selector element The selected operand is ORed with the OPEN POLE OP operand internally to reset the phase selector element Se...

Page 562: ...5 338 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL CONTROL ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 191 Trip output logic Sheet 1 of 2 ...

Page 563: ...CHAPTER 5 SETTINGS CONTROL ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 339 5 Figure 5 192 Trip output logic Sheet 2 of 2 ...

Page 564: ...irst checks for a live phase voltage available from the selected source If voltage is not available the element attempts to use a phase current If neither voltage nor current is available the element does not operate as it does not measure a parameter below the minimum voltage current setting UNDERFREQ 1 MIN VOLT AMP Selects the minimum per unit voltage or current level required to allow the under...

Page 565: ...an increase in frequency If the control systems of the generators do not respond fast enough to quickly ramp the turbine speed back to normal the overspeed can lead to the turbine trip The overfrequency element can be used to control the turbine frequency ramp down at a generating location This element can also be used for feeder reclosing as part of the after load shedding restoration The OVERFRE...

Page 566: ...AX FREQ DIFF 1 00 Hz Range 0 00 to 2 00 Hz in steps of 0 01 SYNCHK1 MAX FREQ HYSTERESIS 0 06 Hz Range 0 00 to 0 10 Hz in steps of 0 01 SYNCHK1 SYNC CLOSE Off Range FlexLogic operand SYNCHK1 S CLS MAX dF 0 50 Hz Range 0 10 to 2 00 Hz in steps of 0 01 SYNCHK1 S CLS MIN dF 0 10 Hz Range 0 01 to 1 00 Hz in steps of 0 01 SYNCHK1 S CLS BRK TIME 0 035 s Range 0 010 to 0 500 s in steps of 0 001 SYNCHK1 V2...

Page 567: ...IFF Selects the maximum primary voltage difference in volts between the two sources A primary voltage magnitude difference between the two input voltages below this value is within the permissible limit for synchronism SYNCHK1 MAX ANGLE DIFF Selects the maximum angular difference in degrees between the two sources An angular difference between the two input voltage phasors below this value is with...

Page 568: ...Selects the combination of dead and live sources that bypass the synchronism check function and permit the breaker to be closed when one or both of the two voltages V1 or and V2 are below the maximum voltage threshold A dead or live source is declared by monitoring the voltage level Six options are available None Dead Source function is disabled LV1 and DV2 Live V1 and Dead V2 DV1 and LV2 Dead V1 ...

Page 569: ...ltage is programmed in one of the sources to be used for synchrocheck An exception is that synchronism cannot be checked between Delta connected phase VTs and a Wye connected auxiliary voltage 2 The relay measures frequency and Volts Hz from an input on a given source with priorities as established by the configuration of input channels to the source The relay uses the phase channel of a three pha...

Page 570: ...5 346 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL CONTROL ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 197 Synchrocheck logic ...

Page 571: ...MENT 1 PICKUP LED This setting enables or disabled the digital element pickup LED When set to Disabled the operation of the pickup LED is blocked DIGITAL ELEMENT 1 DIGITAL ELEMENT 1 FUNCTION Disabled Range Disabled Enabled DIG ELEM 1 NAME Dig Element 1 Range up to 16 alphanumeric characters DIG ELEM 1 INPUT Off Range FlexLogic operand DIG ELEM 1 PICKUP DELAY 0 000 s Range 0 000 to 999999 999 s in ...

Page 572: ... FlexLogic operand is set Consequently the state of these operands can be used as indicators of the integrity of the circuits in which form A contacts are inserted Example 1 Breaker trip circuit integrity monitoring In many applications it is desired to monitor the breaker trip circuit integrity so that problems can be detected before a trip operation is required The circuit is considered to be he...

Page 573: ... 1 to monitor the breaker trip circuit are indicated EnerVista example shown Example 2 Breaker trip circuit integrity monitoring If it is required to monitor the trip circuit continuously independent of the breaker position open or closed a method to maintain the monitoring current flow through the trip circuit when the breaker is open must be provided as shown in the following figure This can be ...

Page 574: ...1 FUNCTION Disabled Range Disabled Enabled COUNTER 1 NAME Counter 1 Range up to 12 alphanumeric characters COUNTER 1 UNITS Range up to six alphanumeric characters COUNTER 1 PRESET 0 Range 2 147 483 648 to 2 147 483 647 COUNTER 1 COMPARE 0 Range 2 147 483 648 to 2 147 483 647 COUNTER 1 UP Off Range FlexLogic operand COUNTER 1 DOWN Off Range FlexLogic operand COUNTER 1 BLOCK Off Range FlexLogic oper...

Page 575: ... 647 COUNTER 1 BLOCK Selects the FlexLogic operand for blocking the counting operation All counter operands are blocked CNT1 SET TO PRESET Selects the FlexLogic operand used to set the count to the preset value The counter sets to the preset value in the following situations When the counter is enabled and the CNT1 SET TO PRESET operand has the value 1 when the counter is enabled and CNT1 SET TO P...

Page 576: ...11 Monitoring elements 5 8 11 1 Menu SETTINGS CONTROL ELEMENTS MONITORING ELEMENTS MONITORING ELEMENTS BREAKER 1 ARCING CURRENT See below BREAKER 4 ARCING CURRENT BREAKER FLASHOVER 1 See page 5 356 BREAKER FLASHOVER 2 BREAKER RESTRIKE 1 See page 5 361 BREAKER RESTRIKE 2 CONTINUOUS MONITOR See page 5 363 CT FAILURE DETECTOR 1 See page 5 364 ...

Page 577: ...sequence has begun is used to initiate this feature A time delay is introduced between initiation and the starting of integration to prevent integration of current flow through the breaker before the contacts have parted This interval includes the operating time of the output relay any other auxiliary CT FAILURE DETECTOR 4 VT FUSE FAILURE 1 See page 5 366 VT FUSE FAILURE 4 OPEN POLE See page 5 367...

Page 578: ...MP INT A C Select the same output operands that are configured to operate the output relays used to trip the breaker In three pole tripping applications configure the same operand to initiate arcing current calculations for poles A B and C of the breaker In single pole tripping applications configure per pole tripping operands to initiate the calculations for the poles that are actually tripped BK...

Page 579: ...CHAPTER 5 SETTINGS CONTROL ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 355 5 Figure 5 203 Breaker arcing current logic ...

Page 580: ...f and no flashover current is flowing A contact showing the breaker status must be provided to the relay The voltage difference is not considered as a condition for open breaker in this part of the logic BREAKER FLASHOVER 1 BKR 1 FLSHOVR FUNCTION Disabled Range Disabled Enabled BKR 1 FLSHOVR SIDE 1 SRC SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 BKR 1 FLSHOVR SIDE 2 SRC None Range None SRC 1 SRC 2 SRC 3 S...

Page 581: ...when the breaker is closed This is well below any typical minimum pickup voltage Select the level of the BRK 1 FLSHOVR DIFF V PKP setting to be less than the voltage difference measured across the breaker when the close or open breaker resistors are left in service Prior to flashover the voltage difference is larger than BRK 1 FLSHOVR DIFF V PKP This applies to either the difference between two li...

Page 582: ...perand can be selected to detect individual breaker pole status and provide flashover detection The recommended setting is 52a breaker contact or another operand defining the breaker poles open status BRK 1 FLSHOVR V PKP This setting specifies a pickup level for the phase voltages from both sides of the breaker If six VTs are available opening the breaker leads to two possible combinations live vo...

Page 583: ... operands per breaker pole that supervise the operation of the element per phase Supervision can be provided by operation of other protection elements breaker failure and close and trip commands A six cycle time delay applies after the selected FlexLogic operand resets BRK FLSHOVR PKP DELAY This setting specifies the time delay to operate after a pickup condition is detected ...

Page 584: ...5 360 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL CONTROL ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 204 Breaker flashover logic ...

Page 585: ...ion of capacitor bank offline as per the breaker pole indication If a high frequency or system frequency current with a magnitude greater than the threshold is resumed at least of a cycle later than the phase current interruption then a BREAKER RESTRIKE 1 BREAKER RESTRIKE 1 FUNCTION Disabled Range Disabled Enabled BKR RESTRIKE 1 BLOCK Off Range FlexLogic operand BREAKER RESTRIKE 1 SOURCE SRC 1 Ran...

Page 586: ...206 Algorithm illustration of state machine to detect restrike In this way a distinction is made between a self extinguishing restrike and permanent breaker failure condition The latter can be detected by the breaker failure function or a regular instantaneous overcurrent element Also a fast succession of restrikes is picked up by breaker failure or instantaneous overcurrent protection The followi...

Page 587: ...ing a breaker open command It must be logic 1 when the breaker is opened either manually or from protection logic BRK RSTR 1 CLS CMD Assigns a FlexLogic operand indicating a breaker close command It must be logic 1 when the breaker is closed Figure 5 207 Breaker restrike logic 5 8 11 5 Continuous monitor SETTINGS CONTROL ELEMENTS MONITORING ELEMENTS CONTINUOUS MONITOR CONTINOUS MONITOR CONT MONITO...

Page 588: ...can detect this state and issue an alarm and or block the tripping of the relay Figure 5 208 Continuous monitor logic 5 8 11 6 CT failure detector SETTINGS CONTROL ELEMENTS MONITORING ELEMENTS CT FAILURE DETECTOR 1 2 or 4 CT FAILURE DETECTOR 1 CT FAIL 1 FUNCTION Disabled Range Disabled Enabled CT FAIL 1 BLOCK Off Range FlexLogic operand CT FAIL 1 3I0 INP 1 SRC 1 Range SRC 1 SRC 2 SRC 3 SRC 4 CT FA...

Page 589: ...K Selects a FlexLogic operand to block operation of the element during some condition for example an open pole in process of the single pole tripping reclosing Local signals or remote signals representing operation of some remote current protection elements via communication channels can also be chosen CT FAIL 1 3I0 INPUT 1 Selects the current source for input 1 The most critical protection elemen...

Page 590: ...ss A failures is a significant level of negative sequence voltage whereas an indication of class B failures is when positive sequence current is present and there is an insignificant amount of positive sequence voltage Also a rapid decrease in the phase voltages magnitude from a healthy voltage level without disturbance in current can indicate VT fuse fail conditions These noted indications of fus...

Page 591: ...do not enable this function because there is no neutral wire for Delta connected VT NEUTRAL WIRE OPEN 1 3 HRAM PKP Specifies the pickup level of 3rd harmonic of 3V0 signal for the NEUTRAL WIRE OPEN DETECTION logic to pick up Base voltage for this element is PHASE VT SECONDARY setting in the case of WYE VTs and PHASE VT SECONDARY in case of DELTA VTs The setting is found under SETTINGS SYSTEM SETUP...

Page 592: ...ue in secondary ohms This setting is relevant if open pole condition at the remote end of the line is to be sensed and utilized by the relay OPEN POLE REM OP FlexLogic operand OPEN POLE REM CURR PKP Specifies pickup level for the remote end current estimated by the relay as the local current compensated by the calculated charging current The latter is calculated based on the local voltages and the...

Page 593: ... of the breaker poles defined in the breaker control feature and available as FlexLogic operand BREAKER 1ΦA CLSD through BREAKER 1 ΦC CLSD and BREAKER 1 OOS are used by the open pole feature if the I AND V AND CBaux detection value is selected For correct operation of the open pole detector the breaker control trip output and single pole autoreclose features must be enabled and configured properly...

Page 594: ...ge SRC 1 SRC 2 SRC 3 SRC 4 THERMAL PROTECTION 1 BASE CURR 0 80 pu Range 0 20 to 3 00 pu in steps of 0 01 THERMAL PROTECTION 1 k FACTOR 1 10 Range 1 00 to 1 20 in steps of 0 05 THERM PROT 1 TRIP TIME CONST 45 min Range 0 to 1000 min in steps of 1 THERM PROT 1 RESET TIME CONST 45 min Range 0 to 1000 min in steps of 1 THERM PROT 1 MINIM RESET TIME 20 min Range 0 to 1000 min in steps of 1 THERM PROT 1...

Page 595: ... and heating that reaches to the final value in two seconds on a step change either step up or step down signal The IEC255 8 cold curve is defined as follows Eq 5 44 The IEC255 8 hot curve is defined as follows Eq 5 45 where top time to operate τop thermal protection trip time constant I measured overload RMS current Ip measured load RMS current before overload occurs k IEC 255 8 k factor applied ...

Page 596: ...ach power cycle When current is greater than the pickup level In k IB element starts increasing the thermal energy Eq 5 47 When current is less than the dropout level In 0 97 k IB the element starts decreasing the thermal energy Eq 5 48 where t is the power cycle duration n is the power cycle index top In is the trip time calculated at index n as per the IEC255 8 cold curve or hot curve equations ...

Page 597: ...nergy is less than 0 05 in all three phases Table 5 41 Typical time constants The figure shows the logic for the thermal overload protection element Figure 5 214 Thermal overload protection logic 5 8 11 10 Broken conductor detection SETTINGS CONTROL ELEMENTS MONITORING ELEMENTS BROKEN CONDUCTOR 1 2 Protected equipment Time constant Minimum reset time Capacitor bank 10 minutes 30 minutes Overhead l...

Page 598: ...setting specifies the ratio of negative sequence current to positive sequence current When one phase conductor is broken the I_2 I_1 ratio with a balanced remaining two phases is 50 So normally you this setting below 50 for example to 30 BROKEN CONDUCTOR 1 I1 MIN This setting specifies the minimum positive sequence current supervision level Ensure this setting is programmed to a sufficient level t...

Page 599: ...CHAPTER 5 SETTINGS CONTROL ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 375 5 Figure 5 215 Broken conductor detection logic ...

Page 600: ...rip DUTT SETTINGS CONTROL ELEMENTS PILOT SCHEMES DUTT SCHEME PILOT SCHEMES DUTT SCHEME See below PUTT SCHEME See page 5 378 POTT SCHEME See page 5 380 POTT1 SCHEME See page 5 383 HYBRID POTT SCHEME See page 5 384 BLOCKING SCHEME See page 5 388 BLOCKING1 SCHEME See page 5 392 DCUB SCHEME See page 5 393 DUTT SCHEME DUTT SCHEME FUNCTION Disabled Range Disabled Enabled DUTT SCHEME BLOCK Off Range Flex...

Page 601: ...purpose DUTT SEAL IN DELAY The output FlexLogic operand DUTT OP is produced according to the DUTT scheme logic A seal in time delay is applied to this operand for coping with noisy communication channels such as a power line carrier The DUTT SEAL IN DELAY is a minimum guaranteed duration of the DUTT OP pulse As this operand activates the Trip Table of the DUTT scheme the trip operands DUTT TRIP A ...

Page 602: ...OL ELEMENTS PILOT SCHEMES PUTT SCHEME PUTT SCHEME PUTT SCHEME FUNCTION Disabled Range Disabled Enabled PUTT SCHEME BLOCK Off Range FlexLogic operand PUTT RX PICKUP DELAY 0 000 s Range 0 000 to 65 535 s in steps of 0 001 PUTT SEAL IN DELAY 0 010 s Range 0 000 to 65 535 s in steps of 0 001 PUTT NO OF COMM BITS 1 Range 1 2 or 4 PUTT RX1 Off Range FlexLogic operand PUTT RX2 Off Range FlexLogic operand...

Page 603: ...t cut out switch are typically used for this purpose PUTT RX PICKUP DELAY This setting enables the relay to cope with spurious receive signals Set this delay longer than the longest spurious TX signal that can be received simultaneously with the zone 1 pickup The selected delay increases the response time of the scheme PUTT SEAL IN DELAY The output FlexLogic operand PUTT OP is produced according t...

Page 604: ...isabled Range Disabled Enabled POTT RX PICKUP DELAY 0 000 s Range 0 000 to 65 535 s in steps of 0 001 TRANS BLOCK PICKUP DELAY 0 020 s Range 0 000 to 65 535 s in steps of 0 001 TRANS BLOCK RESET DELAY 0 090 s Range 0 000 to 65 535 s in steps of 0 001 ECHO DURATION 0 100 s Range 0 000 to 65 535 s in steps of 0 001 ECHO LOCKOUT 0 250 s Range 0 000 to 65 535 s in steps of 0 001 LINE END OPEN PICKUP D...

Page 605: ... of time defined as TRANS BLOCK PICKUP DELAY After that the ground directional overcurrent path is virtually disabled for a period of time specified as TRANS BLOCK RESET DELAY Set the TRANS BLOCK PICKUP DELAY long enough to give the selected ground directional overcurrent function time to operate but not longer than the fastest possible operation time of the protection system that can create curre...

Page 606: ...e directional overcurrent or neutral directional overcurrent elements Both of these elements have separate forward and reverse output operands The forward indication should be used NEG SEQ DIR OC1 FWD or NEUTRAL DIR OC1 FWD For greater security and to overcome spurious directional element operation during transients adding at least 0 5 cycles of pickup delay to the forward directional element is r...

Page 607: ...isabled Enabled Custom POTT1 ECHO COND Off Range FlexLogic operand POTT1 RX PICKUP DELAY 0 000 s Range 0 000 to 65 535 s in steps of 0 001 TRANS BLOCK PICKUP DELAY 0 020 s Range 0 000 to 65 535 s in steps of 0 001 TRANS BLOCK RESET DELAY 0 090 s Range 0 000 to 65 535 s in steps of 0 001 ECHO DURATION 0 100 s Range 0 000 to 65 535 s in steps of 0 001 ECHO LOCKOUT 0 250 s Range 0 000 to 65 535 s in ...

Page 608: ...esponses of various protection elements or to apply extra security conditions through FlexLogic equations this signal is primarily meant to be the output operand from either the Negative Sequence Directional IOC or Neutral Directional IOC Both of these elements have separate forward FWD and reverse REV output operands The forward indication is used NEG SEQ DIR OC1 FWD or NEUTRAL DIR OC1 FWD Figure...

Page 609: ...4 phase and ground distance elements must be enabled configured and set per rules of distance relaying Enable the line pickup element configure it and set properly to detect line end open weak infeed and undervoltage conditions If used by the scheme the selected ground directional overcurrent function s must be enabled configured and set accordingly HYB POTT WEAK INFEED Enabled Range Disabled Enab...

Page 610: ...the HYB POTT PERMISSIVE ECHO is set to Custom HYB POTT WEAK INFEED If this setting is set to Enabled the scheme activates both the keying and operating paths using a pre programmed weak infeed logic see logic diagram below If this setting is set to Custom the weak infeed condition is to be specified by the user via the HYB POTT W I COND setting HYB POTT W I COND This setting specifies user selecte...

Page 611: ...DIR OC1 FWD Coordinate the selected protection element or elements in combination with the selection of GND DIR O C REV For all the forward external faults seen by an element used as GND DIR O C FWD at one end of the line the reverse looking element used as GND DIR O C REV at the other end picks up and provides a blocking signal For greater security and to overcome spurious directional element ope...

Page 612: ...ybrid POTT scheme logic 5 8 12 7 Directional comparison blocking SETTINGS CONTROL ELEMENTS PILOT SCHEMES BLOCKING SCHEME BLOCKING SCHEME BLOCKING SCHEME FUNCTION Disabled Range Disabled Enabled BLOCK SCHEME BLOCK Off Range FlexLogic operand BLOCK RX CO ORD PKP DELAY 0 010 s Range 0 000 to 65 535 s in steps of 0 001 ...

Page 613: ...nds DIR BLOCK TX INIT and DIR BLOCK TX1 STOP through DIR BLOCK TX4 STOP that control the transmission of signals to the remote end s When used with telecommunications facilities assign the output operands to operate output contacts connected to key the transmitter at the interface The output operands from the scheme DIR BLOCK A B C and 3P must be configured to interface with other relay functions ...

Page 614: ...ystems within the reach of the ground directional function used by the blocking scheme to make sure that the ground directional function is not jeopardized during delayed breaker operations BLOCK SCHEME SEAL IN DELAY The output FlexLogic operand DIR BLOCK OP is produced according to the Blocking scheme logic The BLOCK SCHEME SEAL IN DELAY defines a minimum guaranteed duration of the DIR BLOCK OP p...

Page 615: ...TX1 FlexLogic operand For tripping the scheme responds to lack of the blocking signal on bit 1 BLOCK SCHEME RX1 setting The scheme uses only local fault type identification provided by the phase selector to assert the output operands DIR BLOCK TRIP A B C and 3P To take advantage of the four bit blocking scheme initiate the blocking signals from a disturbance detector This can be accomplished by us...

Page 616: ...ting operation of the scheme Good directional integrity is the key requirement for an over reaching forward looking protection element BLOCKING1 SCHEME BLOCKING1 SCHEME FUNCTION Disabled Range Disabled Enabled BLOCK1 SCHEME BLOCK Off Range FlexLogic operand BLOCK1 RX CO ORD PKP DELAY 0 010 s Range 0 000 to 65 535 s in steps of 0 001 TRANS BLOCK1 PICKUP DELAY 0 030 s Range 0 000 to 65 535 s in step...

Page 617: ... of various protection elements or to apply extra conditions through FlexLogic equations BLK1 SCHME DIR REV entries are primarily meant to be the output operand from the Negative Sequence Directional REV IOC Neutral Directional REV IOC non directional IOC or reverse looking distance elements Coordinate the selected protection element or elements in combination with the selection of DIR FWD For all...

Page 618: ...35 s in steps of 0 001 LINE END OPEN PICKUP DELAY 0 050 s Range 0 to 65 535 s in steps of 0 001 DCUB LOG PICKUP DELAY 0 008 s Range 0 to 65 535 s in steps of 0 001 GUARD HEALTHY RESET DELAY 0 015 s Range 0 to 65 535 s in steps of 0 001 DCUB LOG TRIP WINDOW 0 150 s Range 0 to 65 535 s in steps of 0 001 DCUB SEAL IN DELAY 0 010 s Range 0 to 65 535 s in steps of 0 001 DCUB NO OF COMM BITS 1 Range 1 2...

Page 619: ...ontacts in particular Typically you program the output operands to initiate a trip breaker fail and autoreclose and drive a user programmable LED as per the intended application When used in conjunction with the trip output element the scheme is pre configured to initiate trip breaker fail and autoreclose actions DCUB BLOCK This setting allows the user to assign any FlexLogic operand to block the ...

Page 620: ...ts on an adjacent line so that extended blocking action can be established Take into account the pickup time of the reverse looking elements of the scheme To avoid locking up a spurious reverse fault indication that can occur during internal fault conditions do not set the delay defined by this setting too short TRANS BLOCK RESET DELAY This setting defines a transient blocking mechanism embedded i...

Page 621: ...imum guaranteed duration of the DCUB OP pulse As this operand runs the trip table of the directional comparison unblocking scheme the DCUB TRIP A DCUB TRIP B DCUB TRIP C and DCUB TRIP 3P trip operands are sealed in for the same period of time DCUB NO OF COMM BITS This setting specifies the number of bits available on the communications channel for the scheme With only one bit available the scheme ...

Page 622: ...5 398 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL CONTROL ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 223 Directional comparison unblocking scheme logic ...

Page 623: ...Protection Only AR BLOCK BKR1 Off Range FlexLogic operand AR CLOSE TIME BKR 1 0 10 s Range 0 00 to 655 35 s in steps of 0 01 AR BKR MAN CLOSE Off Range FlexLogic operand AR BLK TIME UPON MAN CLS 10 00 s Range 0 00 to 655 35 s in steps of 0 01 AR 1P INIT Off Range FlexLogic operand AR 3P INIT Off Range FlexLogic operand AR 3P TD INIT Off Range FlexLogic operand AR MULTI P FAULT Off Range FlexLogic ...

Page 624: ...e according to the fault type and reclose mode the second breaker should follow the successful reclosure of the first breaker When reclosing simultaneously for the first shot both breakers should reclose with either the single pole or three pole dead time according to the fault type and the reclose mode AR DEAD TIME 1 EXTENSION 0 50 s Range 0 00 to 655 35 s in steps of 0 01 AR RESET Off Range Flex...

Page 625: ...ses the AR 3 P DEAD TIME 1 for the first shot if the fault is single phase If the fault is multi phase the scheme goes to Lockout without reclosing If two or more shots are enabled the second third and fourth shots are always three phase and start the AR 3 P DEAD TIME 2 4 timers 3 Pole B In this mode the autorecloser is initiated for any type of fault and starts the AR 3 P DEAD TIME 1 for the firs...

Page 626: ...e and assume a permanent fault on the line Also assume the scheme is in the Reset state For the first single phase fault the AR 1 P DEAD TIME timer is started while for the first multi phase fault the AR 3 P DEAD TIME 1 timer is started If the AR 3P TD INIT signal is high the AR 3 P DEAD TIME 2 starts for the first shot If AR MAX NO OF SHOTS is set to 1 upon the first reclose the shot counter is s...

Page 627: ...hen a reclose sequence starts by an initiate signal the scheme moves into the reclose in progress state and starts the incomplete sequence timer The setting of this timer determines the maximum time interval allowed for a single reclose shot If a close breaker 1 or 2 signal is not present before this time expires the scheme goes to Lockout There are four other conditions that can take the scheme t...

Page 628: ...Pole Mode 2 1 Pole Mode 3 3 Pole A and Mode 4 3 Pole B which functions in conjunction with signals received at the initiation inputs as described The autorecloser runs in this mode until a different mode is activated through the AR Mode Activation inputs explained as follows Mode 1 to Mode 4 Activation This setting selects an operand for activating the corresponding AR mode in runtime Mode change ...

Page 629: ...t that indicates breaker status AR 3 P DEAD TIME 1 This is the dead time following the first three pole trip This intentional delay can be used for a high speed three pole autoreclose Set it longer than the estimated de ionizing time following the three pole trip AR 3 P DEAD TIME 2 This is the dead time following the second three pole trip or initiated by the AR 3P TD INIT input This intentional d...

Page 630: ...breaker 2 is blocked When set to Yes the closing command is transferred direct to breaker 1 without waiting the transfer time When set to No the closing command is blocked by the AR BKR2 BLK signal and the scheme is sent to lockout by the incomplete sequence timer AR BKR1 FAIL OPTION This setting establishes how the scheme performs when the breaker closing sequence is 1 2 and Breaker 1 has failed ...

Page 631: ...e AR activation inputs in each protection pass The AR mode is switched to the new mode when Only one of four activation inputs is high and AP RIP operand is low and The mode to be activated is different from the current AR mode The logic allows activation of one mode at a time Simultaneous multiple activations are ignored and mode switching does not happen However a FlexLogic operand AR MODE SWITC...

Page 632: ...that the relay uses the last used mode on power up The AR mode resets to the default mode specified by the AR MODE setting when any settings in the autoreclose function are changed Figure 5 225 Mode control logic In addition the current AR mode is available as FlexLogic Operands because AR Mode equals to 1 2 3 and 4 respectively so that it can be monitored and logged ...

Page 633: ...CHAPTER 5 SETTINGS CONTROL ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 409 5 Figure 5 226 Single pole autoreclose logic Sheet 2 of 3 ...

Page 634: ...5 410 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL CONTROL ELEMENTS CHAPTER 5 SETTINGS 5 Figure 5 227 Single pole autoreclose logic Sheet 3 of 3 ...

Page 635: ...CHAPTER 5 SETTINGS CONTROL ELEMENTS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 5 411 5 Figure 5 228 Example of reclosing sequence ...

Page 636: ...s faults FREQ RATE 1 OC SUPV PICKUP This setting defines minimum current level required for operation of the element The supervising function responds to the positive sequence current Typical application includes load shedding Set the pickup threshold to 0 020 if no overcurrent supervision is required FREQ RATE 1 MIN FREQUENCY This setting defines the minimum frequency level required for operation...

Page 637: ...as for load shedding set this setting to the required frequency level Figure 5 229 Frequency rate of change logic 5 9 Inputs outputs 5 9 1 Contact inputs SETTINGS INPUTS OUTPUTS CONTACT INPUTS If the signal source assigned to the frequency rate of change element is only set to auxiliary VT then the minimum voltage supervision is 3 V CONTACT INPUTS CONTACT INPUT H5a CONTACT INPUT H5a ID Cont Ip 1 R...

Page 638: ...d eight times in a power system cycle The protection pass duration is controlled by the frequency tracking mechanism The FlexLogic operand reflecting the debounced state of the contact is updated at the protection pass following the validation marks no 3 and 4 on the figure that follows The update is performed at the beginning of the protection pass so all protection and control functions as well ...

Page 639: ...n the Event Records menu make the following settings changes CONTACT INPUT H5a ID Breaker Closed 52b CONTACT INPUT H5a EVENTS Enabled Note that the 52b contact is closed when the breaker is open and open when the breaker is closed 5 9 2 Virtual inputs SETTINGS INPUTS OUTPUTS VIRTUAL INPUTS VIRTUAL INPUT 1 64 The virtual inputs and outputs are digital signals associated with UR series internal logi...

Page 640: ...lexLogic equations If the operand is to be used anywhere other than internally in a FlexLogic equation it likely needs to be lengthened in time A FlexLogic timer with a delayed reset can perform this function Figure 5 231 Virtual inputs logic 5 9 3 Contact outputs 5 9 3 1 Digital outputs SETTINGS INPUTS OUTPUTS CONTACT OUTPUTS CONTACT OUTPUT H1 A contact inputs and outputs are digital signals asso...

Page 641: ...le FlexLogic operand OUTPUT H1 SEAL IN Cont Op 1 IOn CONTACT OUTPUT H1 EVENTS Enabled Figure 5 232 Contact input output module type 6A contact 1 logic 5 9 3 2 Latching outputs SETTINGS INPUTS OUTPUTS CONTACT OUTPUTS CONTACT OUTPUT H1a The latching output contacts are mechanically bi stable and controlled by two separate open and close coils As such they retain their position even if the relay is n...

Page 642: ...ate dominant and opens if set to Reset dominant Figure 5 233 Contact input output module type 4L contact 1 logic Application example 1 A latching output contact H1a is to be controlled from two user programmable pushbuttons buttons number 1 and 2 The following settings are applied Program the Latching Outputs by making the following changes in the SETTINGS INPUTS OUTPUTS CONTACT OUTPUTS CONTACT OU...

Page 643: ...f 20 ms is required to implement this functionality Write the following FlexLogic equation EnerVista example shown Set both timers Timer 1 and Timer 2 to 20 ms pickup and 0 ms dropout Program the Latching Outputs by making the following changes in the SETTINGS INPUTS OUTPUTS CONTACT OUTPUTS CONTACT OUTPUT H1a and CONTACT OUTPUT H1c menus assuming an H4L module OUTPUT H1a OPERATE VO1 OUTPUT H1a RES...

Page 644: ...emote relay connected to channels 1 and 2 of the local relay by assigning the desired FlexLogic operand to be sent via the selected communications channel This relay allows the user to create distributed protection and control schemes via dedicated communications channels Some examples are directional comparison pilot schemes and transfer tripping Note that failures of communications channel affec...

Page 645: ...vides eight direct outputs that are conveyed on communications channel 1 numbered 1 1 through 1 8 and eight direct outputs that are conveyed on communications channel 2 numbered 2 1 through 2 8 Each digital point in the message must be programmed to carry the state of a specific FlexLogic operand The settings are used to select the operand that represents a specific function as selected by the use...

Page 646: ...ess the RESET pushbutton with none of the annunciator windows selected to acknowledge reset all annunciator windows on that page To acknowledge reset a specific annunciator window use the Up Down Left and Right pushbuttons to select the window and press the RESET or ENTER pushbutton All annunciator windows can be reset remotely by programming a Virtual Input for example Virtual Input 1 as the inpu...

Page 647: ...e the channel as the input parameter to features designed to measure this type of parameter The DCMA INPUT H1 RANGE setting specifies the mA DC range of the transducer connected to the input channel The DCMA INPUT H1 MIN VALUE and DCMA INPUT H1 MAX VALUE settings are used to program the span of the transducer in primary units For example a temperature transducer might have a span from 0 to 250 C i...

Page 648: ...ate an output contact directly See the following table for reference temperature values for each RTD type Table 5 44 RTD temperature vs resistance Temperature Resistance in ohms C F 100 Ω Pt DIN 43760 120 Ω Ni 100 Ω Ni 10 Ω Cu 50 58 80 31 86 17 71 81 7 10 40 40 84 27 92 76 77 30 7 49 30 22 88 22 99 41 82 84 7 88 20 4 92 16 106 15 88 45 8 26 10 14 96 09 113 00 94 17 8 65 0 32 100 00 120 00 100 00 9...

Page 649: ...r Both the output range and a signal driving a given output are user programmable via the following settings menu an example for channel M5 is shown The relay checks the driving signal x in equations below for the minimum and maximum limits and subsequently re scales so the limits defined as MIN VAL and MAX VAL match the output range of the hardware defined as RANGE The following equation is appli...

Page 650: ...xElement base units DCMA OUTPUT H1 MAX VAL This setting allows setting the maximum limit for the signal that drives the output This setting is used to control the mapping between an internal analog value and the output current The setting is entered in per unit values The base units are defined in the same manner as the FlexElement base units Three application examples follow Example Power monitor...

Page 651: ... 5000 5 and the maximum load current is 4200 A The current is to be monitored from 0 A upwards allowing for 50 overload The phase current with the 50 overload margin is Eq 5 55 The base unit for current see the FlexElements section in this chapter for additional details is Eq 5 56 The minimum and maximum power values to be monitored in pu are Eq 5 57 The following settings are entered DCMA OUTPUT ...

Page 652: ...ETTINGS TESTING TEST MODE FUNCTION The L90 provides a test facility to verify the functionality of contact inputs and outputs some communication functions and the phasor measurement unit where applicable using simulated conditions The test mode can be in any of three states Disabled Isolated or Forcible The Disabled mode is intended for normal in service operation relay protection control and comm...

Page 653: ...cted either through the front panel through EnerVista UR Setup or through IEC 61850 control to LLN0 Mod LLN0 Mod ctlVal on selects Disabled test blocked selects Isolated and test selects Forcible The TEST MODE FUNCTION setting can only be changed by a direct user command Following a restart power up settings upload or firmware upgrade the test mode remains at the last programmed value This allows ...

Page 654: ...t bit 15 in the STAT word is set The Sim bit in all output datasets is set PMU 1 VB TEST MAGNITUDE 500 00 kV Range 0 00 to 700 00 kV in steps of 0 01 PMU 1 VB TEST ANGLE 120 00 Range 180 00 to 180 00 in steps of 0 05 PMU 1 VC TEST MAGNITUDE 500 00 kV Range 0 00 to 700 00 kV in steps of 0 01 PMU 1 VC TEST ANGLE 120 00 Range 180 00 to 180 00 in steps of 0 05 PMU 1 VX TEST MAGNITUDE 500 00 kV Range 0...

Page 655: ...contact outputs While in Forcible test mode the relay contact outputs can be pre programmed to respond in the following ways If set to Normal the contact output remains fully operational It operates when its control operand is logic 1 and resets when its control operand is logic 0 If set to Energized the output closes and remains closed while the operand selected by the TEST MODE FORCING setting i...

Page 656: ...ions established by both relays See the Commissioning chapter for information on using the channel tests On restart the TEST MODE FORCING setting and the force contact input and force contact output settings revert to their default states CHANNEL TESTS LOCAL LOOPBACK See below REMOTE LOOPBACK See below LOCAL LOOPBACK LOCAL LOOPBACK FUNCTION No Range Yes No LOCAL LOOPBACK CHANNEL NUMBER 1 Range 1 2...

Page 657: ... 6 1 Actual Values menu ACTUAL VALUES FRONT PANEL Access in EnerVista See page 6 3 ACTUAL VALUES STATUS CONTACT INPUTS See page 6 4 VIRTUAL INPUTS See page 6 4 RxGOOSE BOOLEANS See page 6 5 RxGOOSE DPS See page 6 5 DIRECT INPUTS See page 6 5 CONTACT OUTPUTS See page 6 5 VIRTUAL OUTPUTS See page 6 6 RxGOOSE STATUS See page 6 6 RxGOOSE STATISTICS See page 6 6 AUTORECLOSE See page 6 7 CHANNEL TESTS S...

Page 658: ...TxGOOSE STATUS See page 6 11 ACTUAL VALUES METERING 87L DIFFERENTIAL CURRENT See page 6 16 SOURCE SRC 1 See page 6 17 SOURCE SRC 2 SOURCE SRC 3 SOURCE SRC 4 SENSITIVE DIRECTIONAL POWER See page 6 23 SYNCHROCHECK See page 6 23 TRACKING FREQUENCY See page 6 24 FREQUENCY RATE OF CHANGE See page 6 24 FLEXELEMENTS See page 6 24 RxGOOSE Analogs See page 6 25 WATTMETRIC GROUND FAULT 1 See page 6 25 WATTM...

Page 659: ... and standard front panels To view the front panel in EnerVista software 1 Click Actual Values Front Panel VOLTS PER HERTZ 2 RESTRICTED GROUND FAULT CURRENTS See page 6 27 TRANSDUCER I O DCMA INPUTS See page 6 27 TRANSDUCER I O RTD INPUTS See page 6 27 DISTANCE See page 6 27 ACTUAL VALUES RECORDS FAULT REPORTS See page 6 29 EVENT RECORDS See page 6 30 OSCILLOGRAPHY See page 6 32 DATA LOGGER See pa...

Page 660: ...rms of the default name array index The second line of the display indicates the logic state of the contact input 6 3 2 Virtual inputs ACTUAL VALUES STATUS VIRTUAL INPUTS The present status of the 64 virtual inputs is shown here The first line of a message display indicates the ID of the virtual input For example Virt Ip 1 refers to the virtual input in terms of the default name The second line of...

Page 661: ...TUS CONTACT OUTPUTS RxGOOSE BOOLEANS RxGOOSE BOOLEAN 1 STATUS Off Range On Off RxGOOSE BOOLEAN 256 STATUS Off Range On Off The L90 is provided with optional IEC 61850 capability This feature is specified as a software option at the time of ordering See the Order Codes section of chapter 2 for details RxGOOSE DPS RxGOOSE DPS 1 Status Intermediate Range On Off Intermediate Bad RxGOOSE DPS 16 Status ...

Page 662: ...output in terms of the default name array index The second line of the display indicates the logic state of the virtual output as calculated by the FlexLogic equation for that output 6 3 8 RxGOOSE status ACTUAL VALUES STATUS RxGOOSE STATUS The All RxGOOSE Online actual value does not consider RxGOOSE that are not configured or are not used by any RxGOOSE Input 6 3 9 RxGOOSE statistics ACTUAL VALUE...

Page 663: ...eption modes It is not relevant for GOOSE or for R GOOSE in unicast reception mode 6 3 10 Autoreclose ACTUAL VALUES STATUS AUTORECLOSE The automatic reclosure shot count is shown here where the shot count is the number of reclosures that can be attempted before reclosure goes to lockout If the status reads not available try enabling and configuring the function under SETTINGS CONTROL ELEMENTS AUTO...

Page 664: ...ith local remote GPS clock source VALIDITY OF CHANNEL CONFIGURATION The current state of the communications channel identification check and hence validity displays here If a remote relay ID number does not match the programmed number at the local relay the FAIL value displays The n a value appears if the local relay ID is set to a default value of 0 or if the 87L element is disabled See the SETTI...

Page 665: ...G SELECTOR SWITCHES SELECTOR SWITCH 1 POSITION 0 7 Range Current Position 7 SELECTOR SWITCH 2 POSITION 0 7 Range Current Position 7 FLEX STATES PARAM 1 Off Off Range On Off PARAM 256 Off Off Range On Off ETHERNET ETHERNET PRI LINK STATUS Fail Range Fail OK ETHERNET SEC LINK STATUS Fail Range Fail OK ETHERNET TER LINK STATUS Fail Range Fail OK REAL TIME CLOCK SYNCHRONIZING RTC SYNC SOURCE None Rang...

Page 666: ...operational Synchronized if synchronized PTP IRIG B DELTA is the time difference measured in nanoseconds between the fractional seconds portion of the time being received via PTP and that being received via IRIG B A positive value indicates that PTP time is fast compared to IRIG B time 6 3 17 Remaining connection status ACTUAL VALUES STATUS COMM STATUS REMAINING CONNECT These values specify the re...

Page 667: ... R GOOSE transmission requires Address Resolution Protocol ARP for the resolution of the network layer address into the MAC layer address R TxGOOSE ARP status On indicates that ARP responses are being received and the destination MAC address for R GOOSE transmissions has been obtained This status remains Off if TxGOOSE is not configured for R GOOSE It also remains Off if setting R TxGOOSE1 DST IP ...

Page 668: ... GOOSE transmission with setting R TxGOOSE1 DST IP set to a unicast IP address It is not applicable for GOOSE or for R GOOSE when setting R TxGOOSE1 DST IP is multicast 6 4 Metering 6 4 1 Metering conventions 6 4 1 1 UR convention for measuring power and energy The figure illustrates the conventions established for use in UR devices ...

Page 669: ...Figure 6 2 Flow direction of signed values for watts and VARs 6 4 1 2 UR convention for measuring phase angles All phasors calculated by URs and used for protection control and metering functions are rotating phasors that maintain the correct phase angle relationships with each other at all times ...

Page 670: ...ion is not measurable the phase angles are not referenced The phase angles are assigned as positive in the leading direction and are presented as negative in the lagging direction to more closely align with power system metering conventions The figure illustrates this Figure 6 3 UR phase angle measurement convention 6 4 1 3 UR convention for measuring symmetrical components The URs calculate volta...

Page 671: ...ectively This however is a relative matter It is important to remember that the L90 displays are always referenced as specified under SETTINGS SYSTEM SETUP POWER SYSTEM FREQUENCY AND PHASE REFERENCE The example above is illustrated in the following figure Figure 6 4 Measurement convention for symmetrical components ABC phase rotation ACB phase rotation SYSTEM VOLTAGES sec V VT conn relay INPUTS se...

Page 672: ... the local relay Terminal 1 refers to the communication channel 1 interface to a remote L90 at terminal 1 Terminal 2 refers to the communication channel 2 interface to a remote L90 at terminal 2 87L DIFFERENTIAL CURRENT LOCAL IA 0 000 A 0 0 LOCAL IB 0 000 A 0 0 LOCAL IC 0 000 A 0 0 TERMINAL 1 IA 0 000 A 0 0 TERMINAL 1 IB 0 000 A 0 0 TERMINAL 1 IC 0 000 A 0 0 TERMINAL 2 IA 0 000 A 0 0 TERMINAL 2 IB...

Page 673: ...es are unavailable 6 4 3 2 Phase current metering ACTUAL VALUES METERING SOURCE SRC 1 PHASE CURRENT SOURCE SRC 1 PHASE CURRENT SRC 1 See below GROUND CURRENT SRC 1 See page 6 18 PHASE VOLTAGE SRC 1 See page 6 18 AUXILIARY VOLTAGE SRC 1 See page 6 19 POWER SRC 1 See page 6 19 ENERGY SRC 1 See page 6 20 DEMAND SRC 1 See page 6 20 FREQUENCY SRC 1 See page 6 21 CURRENT HARMONICS SRC 1 See page 6 22 VO...

Page 674: ...e programmed by the user for the associated source see SETTINGS SYSTEM SETUP SIGNAL SOURCES 6 4 3 4 Phase voltage metering ACTUAL VALUES METERING SOURCE SRC 1 PHASE VOLTAGE SRC 1 PHASOR In 0 000 A 0 0 SRC 1 ZERO SEQ I0 0 000 A 0 0 SRC 1 POS SEQ I1 0 000 A 0 0 SRC 1 NEG SEQ I2 0 000 A 0 0 GROUND CURRENT SRC 1 SRC 1 RMS Ig 0 000 A SRC 1 PHASOR Ig 0 000 A 0 0 SRC 1 PHASOR Igd 0 000 A 0 0 PHASE VOLTAG...

Page 675: ...er for the associated source see SETTINGS SYSTEM SETUP SIGNAL SOURCES 6 4 3 6 Power metering ACTUAL VALUES METERING SOURCE SRC 1 POWER SRC 1 PHASOR Vca 0 000 V 0 0 SRC 1 ZERO SEQ V0 0 000 V 0 0 SRC 1 POS SEQ V1 0 000 V 0 0 SRC 1 NEG SEQ V2 0 000 V 0 0 AUXILIARY VOLTAGE SRC 1 SRC 1 RMS Vx 0 00 V SRC 1 PHASOR Vx 0 000 V 0 0 POWER SRC 1 SRC 1 REAL POWER 3φ 0 000 W SRC 1 REAL POWER φa 0 000 W SRC 1 RE...

Page 676: ...t phasors VAB and VCB are phase to phase voltage phasors Î is the conjugate of I 6 4 3 7 Energy metering ACTUAL VALUES METERING SOURCE SRC 1 ENERGY This menu displays metered values for real and reactive energy The SRC 1 text is replaced by the name programmed by the user for the associated source see SETTINGS SYSTEM SETUP SIGNAL SOURCES Because energy values are accumulated record them and then r...

Page 677: ...ing ACTUAL VALUES METERING SOURCE SRC 1 FREQUENCY The metered frequency values are displayed in this menu The SRC 1 text is replaced by the name programmed by the user for the associated source see SETTINGS SYSTEM SETUP SIGNAL SOURCES SOURCE FREQUENCY is measured via software implemented zero crossing detection of an AC signal The signal is either a Clarke transformation of three phase voltages or...

Page 678: ...ALUES METERING SOURCE SRC 1 VOLTAGE HARMONICS This menu displays metered voltage harmonics values The SRC 1 text is replaced by the programmed name for the associated source see the SETTINGS SYSTEM SETUP SIGNAL SOURCES menu To extract the 2nd to 25th voltage harmonics each harmonic is computed on a per phase basis where N 64 is the number of samples per cycle ω0 2πf is the angular frequency based ...

Page 679: ... of the RCA and CALIBRATION settings 6 4 5 Synchrocheck ACTUAL VALUES METERING SYNCHROCHECK SYNCHROCHECK 1 10 If synchrocheck or a setting is Disabled the corresponding actual values menu item does not display Voltage harmonics are calculated only for Wye connected phase VTs Ensure that the SYSTEM SETUP AC INPUTS VOLTAGE BANK F5 PHASE VT XX CONNECTION setting is Wye to enable voltage harmonics met...

Page 680: ...g IB and IC Diff Curr IA Mag IB and IC Terminal 1 IA Mag IB and IC Terminal 2 IA Mag IB and IC IBASE maximum primary RMS value of the IN and IN inputs CT primary for source currents and 87L source primary current for line differential currents 87L SIGNALS Op Square Curr IA IB and IC Rest Square Curr IA IB and IC BASE Squared CT secondary of the 87L source BREAKER ACC ARCING AMPS Brk X Acc Arc Amp ...

Page 681: ...VTSecondary and PhaseCTSecondary are the secondary nominal voltage and the secondary nominal current of the distance source In case multiple CT inputs are summed as one source current and mapped as the distance source use the PhaseCTSecondary value from the CT with the highest primary nominal current Distance source is specified in setting under SETTINGS GROUPED ELEMENTS SETTING GROUP 1 6 DISTANCE...

Page 682: ...ate network loading The PDU size shown in the displays does not include the Ethernet UDP or IP layers PDU sizes approaching approximately 1500 bytes result in fragmented data frames causing increased network traffic 6 4 13 Volts per hertz ACTUAL VALUES METERING VOLTS PER HERTZ 1 2 This menu displays the data for volts per hertz PMU 1 V2 0 000 V 0 00 PMU 1 V0 0 000 V 0 00 Range Substituted with zer...

Page 683: ... programmed units ACTUAL VALUES METERING TRANSDUCER I O RTD INPUTS RTD INPUT xx Actual values for each RTD input channel that is enabled are displayed with the top line as the programmed channel ID and the bottom line as the value 6 4 16 Distance ACTUAL VALUES METERING DISTANCE RESTRICTED GROUND FAULT 1 RGF 1 DIFF Igd 0 000 A RGF 1 RESTR Igr 0 000 A DCMA INPUT xx DCMA INPUT xx 0 000 mA RTD INPUT x...

Page 684: ...ositive sequence impedance ratio both are settings taken from the first enabled ground distance zone count from zone 1 to zone 5 ZAG ZBG ZCG are calculated only if at least one ground distance zone is enabled otherwise all the metering quantities for ground distance impedance ZAG ZBG and ZCG are reset to zero including magnitude and angle Note that VTs of the distance source must be connected in W...

Page 685: ... between the local terminal and the tap point the operand TAP LOCAL FAULT is then asserted high at the local relay The FAULT 1 FAULT RESIST displays the fault resistance at the fault point which is shown in the secondary ohms The calculation is explained in the Theory of Operation chapter The FAULT 1 LOOP RESISTANCE and REACTANCE are expressed in secondary ohms When the multi ended fault location ...

Page 686: ... impedance 6 5 2 Event records 6 5 2 1 Enhanced and standard front panels ACTUAL VALUES RECORDS EVENT RECORDS Fault type Vloop Iloop AG VA IA Z0 Z1 1 I0 Z0M Z1 IG 3 BG VB IB Z0 Z1 1 I0 Z0M Z1 IG 3 CG VC IC Z0 Z1 1 I0 Z0M Z1 IG 3 AB ABG VA VB IA IB BC BCG VB VC IB IC CA CAG VC VA IC IA ABC Average of AB BC CA loop impedances VTs of the FAULT REPORT 1 SOURCE must be connected in Wye or VT SUBSTITUTI...

Page 687: ... them in a web browser enter the IP address of the device When an oscillography icon displays click it to open it Figure 6 5 Event records viewed in EnerVista software 6 5 2 2 Graphical front panel To display the event records page press the Home pushbutton then the Event Record Tab pushbutton The newest event is always at the top Up and Down pushbuttons move the event selector up and down When th...

Page 688: ... RECORDS menu for information on clearing the oscillography records 6 5 4 Data logger ACTUAL VALUES RECORDS DATA LOGGER The OLDEST SAMPLE TIME represents the time at which the oldest available samples were taken It is static until the log gets full at which time it starts counting at the defined sampling rate The NEWEST SAMPLE TIME represents the time the most recent samples were taken It counts u...

Page 689: ...GGERS 0 Range 0 to 65535 in steps of 1 PMU 1 RECORDING See below PMU 1 RECORDINg PMU 1 FORCE TRIGGER Yes Range No Yes PUM 1 AVAILABLE RECORDS 0 Range 0 to 65535 in steps of 1 PUM 1 SECONDS PER RECORD 0 0 Range 0 to 6553 5 in steps of 0 1 PUM 1 LAST CLEARED 2013 07 14 15 40 16 Range YYYY MM DD HH MM SS BREAKER 1 BKR 1 ACC ARCING AMP φA 0 00 kA2 cyc BKR 1 ACC ARCING AMP φB 0 00 kA2 cyc BKR 1 ACC ARC...

Page 690: ...s The MAC address displays for port 1 The MAC address for port 2 is one higher The MAC address for port 3 is one higher than port 2 In redundant mode the MAC addresses for ports 2 and 3 are the same as port 2 6 6 2 Firmware revisions 6 6 2 1 Enhanced and standard front panels ACTUAL VALUES PRODUCT INFO FIRMWARE REVISIONS MODEL INFORMATION ORDER CODE LINE 1 L90 A00 AAA A0A A0A Range standard GE ord...

Page 691: ...AM REVISION 02 02 Range 0 00 to 655 35 Revision number for FPGA FPGA DATE 2016 09 15 16 41 32 Range YYYY MM DD HH MM SS Date and time when the FPGA was built FIRMWARE REVISIONS L90 Relay REVISION 7 6x Range 0 00 to 655 35 Revision number of the application firmware MODIFICATION FILE NUMBER 0 Range 0 to 65535 ID of the MOD FILE Value is 0 for each standard firmware release BOOT PROGRAM REVISION 7 0...

Page 692: ...6 36 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL PRODUCT INFORMATION CHAPTER 6 ACTUAL VALUES 6 ...

Page 693: ...error messages for IEC 61850 are outlined in the UR Family Communications Guide 7 1 Commands menu The commands menu contains relay directives intended for operations personnel All commands can be protected from unauthorized access via the command password see the Security section of chapter 5 for details The following flash message appears after successfully command entry COMMANDS COMMANDS VIRTUAL...

Page 694: ...p 1 Off Range Off On Virt Ip 2 Off Range Off On Virt Ip 64 Off Range Off On COMMANDS CLEAR RECORDS CLEAR FAULT REPORTS No Range No Yes CLEAR EVENT RECORDS No Range No Yes CLEAR OSCILLOGRAPHY No Range No Yes CLEAR DATA LOGGER No Range No Yes CLEAR BREAKER 1 ARCING AMPS No Range No Yes CLEAR BREAKER 2 ARCING AMPS No Range No Yes CLEAR DEMAND RECORDS No Range No Yes CLEAR CHANNEL TEST RECORDS No Rang...

Page 695: ...e effect when the ENTER key is pressed The clock also can be synchronized to the local computer time among several UR devices Use the Synchronize Devices entry in the Online Window area of the EnerVista software Click the button at the top of the window that opens When the relay is synchronizing to an external time source such as PTP IRIG B or SNTP the manually entered time or the manually synchro...

Page 696: ... no impact if there have been no changes to the hardware modules When an update does not occur the ORDER CODE NOT UPDATED message displays REBOOT RELAY Restarts the relay so that changes to configuration settings can take effect In most cases if changes are made to the configuration settings these changes do not take effect unless the relay is rebooted SERVICE COMMAND Performs specific L90 service...

Page 697: ...esent time is before the scheduled one shot time The PMU ONE SHOT OP operand indicates the one shot operation and remains asserted for 30 seconds afterwards When the function is disabled all three operands are de asserted The one shot function applies to all logical PMUs of a given L90 relay Figure 7 1 PMU one shot FlexLogic operands 7 1 5 1 Testing accuracy of the PMU The one shot feature is used...

Page 698: ...ty COMMANDS SECURITY With the CyberSentry option this setting is available to enable or disable the following commands ADMINISTRATOR LOGOFF Selecting Yes allows the Supervisor to forcefully logoff an administrator session ENGINEER LOGOFF Selecting Yes allows the Supervisor to forcefully logoff an engineer session OPERATOR LOGOFF Selecting Yes allows the Supervisor to forcefully logoff an operator ...

Page 699: ...get messages is described below Phase information is included if applicable If a target message status changes the status with the highest priority displays Table 7 1 Target message priority status If a self test error is detected a message appears indicating the cause of the error For example UNIT NOT PROGRAMMED indicates that the minimal relay settings have not been programmed 7 2 2 Relay self t...

Page 700: ...ce Setup If the problem persists contact the factory Latched target message No Description of problem A FlexLogic equation is incorrect How often the test is performed The test is event driven performed whenever FlexLogic equations are modified What to do Finish all equation editing and use self tests to debug any errors Latched target message No Description of problem The PRODUCT SETUP INSTALLATI...

Page 701: ...ess reaches a critical level the message displays persistently on the front panel and no front panel key navigation is possible How often the test is performed The battery is monitored every five seconds The error message displays after 60 seconds if the problem persists What to do Replace the battery as outlined in the Maintenance chapter Latched target message No Description of problem Direct in...

Page 702: ...a latching contact output of an installed type 4L module How often the test is performed Upon initiation of a contact output state change What to do Verify the state of the output contact and contact the factory if the problem persists Latched target message No Description of problem A data item in a configurable GOOSE data set is oscillating How often the test is performed Upon scanning of each c...

Page 703: ...ut not connected How often the test is performed Every second What to do Check direct input and output configuration and wiring Latched target message No Description of problem One or more RxGOOSE messages are not being received How often the test is performed The self test is activated when no message is received within the expected time interval which is the time to live time in the previous mes...

Page 704: ...ss in a web browser then click the SFP Transceiver Information Only the type of SFP displays and not power data What to do A web page SFP Transceiver Information is provided This page displays the type of the SFP in it This data is to be used with the CPU type to know the cause of the problem Latched target message No Description of problem A faulty small form factor pluggable port SFP or unpluggi...

Page 705: ...roblem Seen until the builds is tagged as being release candidate or gold builds What to do Update firmware to either of these builds Description of problem In version 7 41 if more breaker elements are enabled than the number of installed DSP modules the excess elements are not functional and can trigger self test error Module Failure 33 In release 7 42 and later the firmware does not allow enabli...

Page 706: ...e and all contact outputs and shared outputs are de asserted What to do First rectify any Process Bus Trouble and Brick Trouble self test errors Check the actual value of the operand referenced by the Process Bus Failure Operand setting and if On determine the cause and rectify If the problem persists with the foregoing all clear the cause must be an AC input discrepancy which is typically the res...

Page 707: ...oblem Brick internal self testing has detected trouble internal to the Brick Severity This self test error does not directly inhibit protection However some or all of the affected Brick inputs outputs may not be available to the UR device What to do Check the Brick environment for over under temperatures and the voltage of its power source If the ambient temperature and supply voltage are within B...

Page 708: ...7 16 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL TARGETS MENU CHAPTER 7 COMMANDS AND TARGETS 7 ...

Page 709: ...ected burden as follows 1 The CTs should be class TPX or TPY or IEC class 5P20 or better Use class TPZ only after discussion with both the manufacturer of the CT and GE Multilin 2 The CT primary current rating should be somewhat higher than the maximum continuous load current but not too high relative to the minimum fault current because the differential element minimum pickup setting is 0 2 CT ra...

Page 710: ...ne CT at each side is used these equation may not provide correct estimation of the required knee point voltage For this situation GE provides a CT saturation analysis tool described in the following section 8 1 2 CT saturation analysis tool The CT saturation analysis tool is an Excel spreadsheet provided for users to analyze the L90 reliability during CT saturation caused by an external fault to ...

Page 711: ...Figure 8 3 Tool results for differential and restraint currents You are encouraged to test different fault locations and different fault levels and distributions per short circuit studies Alternatively the tool can help to estimate required CT parameters ratio and knee point voltage based on some pre determined criteria 8 2 Current differential 87L settings 8 2 1 Introduction Software is available...

Page 712: ...current is below the breakpoint where CT errors and saturation effects are not expected to be significant The setting is used to provide sensitivity to high impedance internal faults or when system configuration limits the fault current to low values A setting of 10 to 20 is appropriate in most cases but increase this to 30 if the CTs can perform quite differently during faults 8 2 4 Current diffe...

Page 713: ...nal CT ratios The slope value must be identical at all terminals Consider a two terminal configuration with the following CT ratios for relays 1 and 2 Eq 8 4 Consequently we have the following CT tap value for relays 1 and 2 Eq 8 5 To achieve maximum differential sensitivity the minimum pickup is set as 0 2 pu at the terminal with the higher CT primary current in this case 2000 5 for relay 2 The o...

Page 714: ...harging current if the tap and CT ratio settings are chosen correctly 8 2 7 Breaker and a half Assume a breaker and the half configuration shown in the following figure This section provides guidance on configuring the L90 relay for this application The L90 is equipped with two CT VT modules F8F and L8F 1 CTs and VTs are connected to L90 CT VT modules as follows CT1 circuitry is connected to the F...

Page 715: ...RENTIAL SYSTEM INSTRUCTION MANUAL 8 7 8 Figure 8 4 Breaker and a half application 2 The CTs and VTs are configured according to the following ratios and connections EnerVista UR Setup example shown 3 The sources are configured as follows Source 1 First current source for current differential ...

Page 716: ...ocheck 2 Source 3 Current source for distance backup overcurrent Voltage source for distance Voltage source for synchrocheck 1 and 2 Source 4 Voltage source for synchrocheck 1 The EnerVista UR Setup configuration is as follows 4 Sources are assigned accordingly in the specific element menus For current differential set CURRENT DIFF SIGNAL SOURCE 1 to SRC 1 and CURRENT DIFF SIGNAL SOURCE 2 to SRC 2...

Page 717: ...other cases there are no CTs available on the line side of the line to be protected Taking full advantage of L90 capability to support up to four CTs connected directly the relay can be applied to protect both line and buses as shown in the figure Proper CT VT modules must be ordered for such applications The varying CT ratios at the breakers can be compensated locally by using the sources mechani...

Page 718: ...e the 87L element but only enable GPS compensation when valid GPS signals are available This provides less sensitive protection on the loss of the GPS signal at any terminal and runs with higher pickup and restraint settings 8 3 2 Compensation method 1 Enable GPS compensation on the loss of the GPS signal at any terminal and continue to operate the 87L element until a change in the channel round t...

Page 719: ...al is restored and the 87L element is ready to operate 3 Assign virtual output BLOCK 87L VO1 to the 87L Current Differential Block setting SETTINGS GROUPED ELEMENTS SETTING GROUP LINE DIFFERENTIAL CURRENT DIFFERENTIAL CURRENT DIFF BLOCK It can be used to enable backup protection raise an alarm and perform other functions as per the given protection philosophy 8 3 3 Compensation method 2 Enable GPS...

Page 720: ...operand can be used to monitor and signal maximum channel asymmetry Essentially the L90 switches to another setting group with higher pickup and restraint settings sacrificing sensitivity to keep the 87L function operational 1 Create FlexLogic similar to that shown as follows to switch the 87L element to Settings Group 2 with most sensitive settings if the L90 has a valid GPS time reference If a G...

Page 721: ...ications The distance elements can then effectively provide a means of fault identification and clearance However for a line with tapped transformers a number of other issues need to be considered to ensure stability for the L90 Any differential scheme has a potential problem when a low voltage LV fault occurs at the tapped transformer location and the current at the tap is not measured Because th...

Page 722: ...e set much lower typically two times the capacitance charging current of the line The usage of the fuse fail function is also important during double contingency events such as an external fault during fuse fail conditions The current supervision alone does not prevent maloperation in such circumstances Keep in mind that the fuse failure element provided on the L90 needs some time to detect fuse f...

Page 723: ...his element must be set to account for any infeed at the remote bus The time delay must coordinate with other time delayed protections on the next line The use of a lens characteristic or the load encroachment element is advantageous if load limits are a problem To avoid extremely large reach settings the L90 has the ability to implement any element so that it is reverse looking which then can pro...

Page 724: ...case a zone 3 element must be time coordinated with timed clearances on the next section 8 4 3 5 Ground distance zone 4 As a further contribution to a remote backup philosophy the reach of this element must be set to account for any infeed at the remote bus The time delay must coordinate with other time delayed protections on the next line The use of a lens characteristic or load encroachment elem...

Page 725: ... The scheme generates an output operand PUTT TX that is used to transmit the signal to the remote end Choices of communications channel include Remote Inputs Outputs and telecommunications interfaces When used with telecommunications facilities the output operand should be assigned to operate an output contact connected to key the transmitter at the interface The PUTT RX PICKUP DELAY timer can be ...

Page 726: ...an be interrupted by a fault For proper operation of the scheme the Zone 2 phase and ground distance elements must be enabled and configured per rules of distance relaying The Line Pickup element needs to be enabled and configured properly to detect line end open weak infeed conditions If used by this scheme the selected ground directional overcurrent function s must be enabled and configured acco...

Page 727: ... can be preferred over a Hybrid POTT scheme because of shorter reach settings for the Zone 2 elements This follows from the fundamental difference that all zone 2 elements are required to see an internal fault for the POTT approach under all system conditions which in turn means that the reversed Zone 4 block initiate elements must also have an increased reach A blocking scheme on the other hand c...

Page 728: ...tabilizing and contact denouncing This timer determines how long the logic waits before enabling the directional comparison unblocking scheme when the communications channel is restored Operating of the directional comparison unblocking scheme consists of two parts normal operation and loss of guard operation 8 5 7 2 Normal operation Normal operation picks up under the following conditions The sch...

Page 729: ...and DCUB BLOCK is Off and the DCUB PERMISSIVE ECHO setting is Enabled and the LINE PICKUP LEO PKP operand that detects the local breaker to be open picks up for a time set by LINE END OPEN PICKUP DELAY and any permissive signal DCUB RX1 through DCUB RX4 is received and any LOG1 to LOG4 is received and a fault is not seen in the forward zone 2 distance elements or ground directional forward functio...

Page 730: ... oscillations It is strongly recommended to use a power system simulator to verify the reach settings or to use an adaptive L90 feature for dynamic reach control If the adaptive reach control feature is used set the PHS DIST Z1 VOLT LEVEL setting accordingly This setting is a sum of the overvoltage protection levels for all the series capacitors located between the relay potential source and the f...

Page 731: ...ffset cannot be higher than 7 Ω It is recommended to use 5 Ω offset impedance For the Receiving Bus relay bus side VTs Net inductive reactance from relay into local system 5 7 2 Ω 0 there is no need for offset Net inductive reactance from relay through far end busbar 3 10 4 3 Ω the offset cannot be higher than 3 Ω It is recommended to use 1 5 Ω offset impedance For the Receiving Bus relay line sid...

Page 732: ...ly a security factor must be applied to the above stability conditions Alternatively distance supervision can be considered to prevent maloperation due to transformer load currents 8 7 3 LV side faults Use Distance Supervision to prevent maloperation of the L90 protection system during faults on the LV side of the transformer s As explained earlier set the distance elements to overreach all line t...

Page 733: ... frequency and relay sampling frequency does not affect 87L function However instantaneous elements have additional error caused by the sensitivity of Fourier phasor estimation to the difference between signal frequency and tracking frequency To secure instantaneous element operation it is recommended either to use FlexLogic as shown here to block the instantaneous elements during synchronization ...

Page 734: ...t If this is the case set the CT connection setting to transformer connection and vector group as seen from the CTs toward the reach point Otherwise set the CT connection setting to None The voltage signals require compensation if the transformer is located between the VTs and the intended reach point If this is the case set the VT connection setting to transformer connection and vector group as s...

Page 735: ...atio is required The primary impedance must be only re calculated to secondary quantities Eq 8 16 8 9 1 4 Zone 1 setting in application B As the transformer is not located between the potential source and the reach point for Z1 the reach impedance must not include the positive sequence impedance of the transformer The CTs are located on the other side of the transformer thus transformer ratio must...

Page 736: ...LICATION OF SETTINGS 8 The Zone 1 settings are Eq 8 20 PHS DIST Z1 REACH 0 80 PHS DIST Z1 RCA 85 PHS DIST Z1 XMFR VOL CONNECTION None PHS DIST Z1 XMFR CUR CONNECTION Dy1 The Zone 4 settings are Eq 8 21 PHS DIST Z4 REACH 2 60 PHS DIST Z4 RCA 89 PHS DIST Z4 XMFR VOL CONNECTION Yd11 PHS DIST Z4 XMFR CUR CONNECTION None ...

Page 737: ...in slot W in both relays for example W7J 2 Interconnect the two relays using the proper media for example single mode fiber cable observing correct connection of receiving Rx and transmitting Tx communications paths and turn power on to both relays 3 Verify that the Order Code in both relays is correct 4 Cycle power off on in both relays 5 Verify and record that both relays indicate In Service on ...

Page 738: ... communications failures as follows start test as per Steps 13 to 14 and in two to five seconds disconnect the fiber Rx cable on the corresponding channel Expected result The Running Remote Loopback Test message appears When the channel is momentarily cut off the Remote Loopback Test FAILED message displays The status check reads as follows ACTUAL VALUES STATUS CHANNEL TESTS CHANNEL 1 2 LOCAL LOOP...

Page 739: ...ith the following status checks ACTUAL VALUES STATUS CHANNEL TESTS CHANNEL 1 2 STATUS OK ACTUAL VALUES STATUS CHANNEL TESTS REMOTE LOOPBACK STATUS n a ACTUAL VALUES STATUS CHANNEL TESTS PFLL STATUS OK 7 Apply a current of 0 5 pu at a frequency 1 to 3 higher or lower than nominal only to local relay phase A to verify that frequency tracking does not affect PFLL when only one relay has a current inp...

Page 740: ...ENT TERMINAL 1 2 IA along with a phasor of twice the magnitude at ACTUAL VALUES METERING 87L DIFF CURRENT IA DIFF 4 7 Repeat the above tests for Phases B and C 4 8 Restore the communication circuits to normal 9 1 4 Local remote relay tests 9 1 4 1 Direct transfer trip DTT tests The direct transfer trip is a function by which one relay sends a signal to a remote relay to cause a trip of remote equi...

Page 741: ...T CURRENT DIFFERENTIAL menu of both relays CURRENT DIFF FUNCTION Disabled 14 At the Remote relay set SETTINGS INPUTS OUTPUTS CONTACT OUTPUT N1 CONTACT OUTPUT N1 OPERATE to the CURRENT DIFF KEY DTT operand 15 At the Local relay observe under the ACTUAL VALUES STATUS CONTACT OUTPUTS menu that CONTACT OUTPUT N1 N2 and N3 are Off 16 At the Remote relay set SETTINGS TESTING FORCE CONTACT INPUTS FORCE C...

Page 742: ...9 6 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL TESTING CHAPTER 9 COMMISSIONING 9 ...

Page 743: ...width requirements It also improves security by eliminating the possibility of falsely interpreting a single corrupted data sample as a fault The L90 relay system uses a new consolidation technique called phaselets Phaselets are partial sums of the terms involved in a complete phasor computation The use of phaselets in the L90 design improves the transient response performance without increasing t...

Page 744: ...the other relay terminals Also the sum of the squares of the raw data samples is computed for each phase and transmitted with the phaselets At the receiving relay the received phaselets are combined into phasors Also ground current is reconstructed from phase information An elliptical restraint region is computed by combining sources of measurement error In addition to the restraint region a separ...

Page 745: ...tion algorithm is used to enhance security and to improve transient response Conditions to detect a disturbance include the magnitude of zero sequence current the magnitude of negative sequence current and changes in positive negative or zero sequence current Normally differential protection is performed using a full cycle Fourier transform Continuous use of a full cycle Fourier means that some pr...

Page 746: ...s the restraint region When the adaptive portion of the restraint current is small the restraint region shrinks When the adaptive portion of the restraint current increases the restraint region grows to reflect the uncertainty of the measurement The computed severity increases with the probability that the sum of the measured currents indicates a fault With the exception of Restraint all quantitie...

Page 747: ...on uses the same CT matched and time aligned phasors as the phase segregated current differential function The operate signal is calculated for both real and imaginary parts as follows Eq 10 12 Eq 10 13 The terms for the second remote terminal are omitted in two terminal applications The maximum through current is available locally and re constructed from the received remote restraint based on the...

Page 748: ...ys within a plus or minus 25 microsecond error during normal conditions for a two or three terminal system For four or more terminals the error can be somewhat higher depending on the quality of the communications channels The algorithm is unconditionally stable In the case of two and three terminal systems asymmetric communications channel delay is automatically compensated for In all cases an es...

Page 749: ...bsolute time reference used to measure channel asymmetry The local sampling clocks are synchronized to each other in phase and to the power system in frequency The local GPS clocks are synchronized to GPS time using the externally provided GPS time signal GPS time stamp is included in the transmitted packet along with the sampling clock time stamp Both sampling clock deviation and channel asymmetr...

Page 750: ...s frequency synchronism the frequency deviation is approximately the same for each relay The clock deviation frequency is computed from the deviation phasor Eq 10 24 Note that a four quadrant arctangent can be computed by taking the imaginary and the real part of the deviation separately for the two arguments of the four quadrant arctangent Also note that the input to the loop filter is in radian ...

Page 751: ... first message is transmitted by a given relay The second is when the exchange is broken long enough to invalidate the last received set of time stamps if the exchange is broken for longer than 66 ms the time stamps from a given clock can roll over twice invalidating time difference computations In either of these situations the next outgoing set of time stamps is a special start up set containing...

Page 752: ...loop can be underdamped critically damped or over damped For this application critically damped is a good choice This sets a constraint relating the two parameters A second constraint is derived from the desired time constants of the loop By considering the effects of both phase and frequency noise in this application it can be shown that optimum behavior results with a certain proportion between ...

Page 753: ... between execution of the filter algorithm Tphase time constant for the primary phase locked loop Tfrequency time constant for the frequency locked loop 10 1 13 Matching phaselets An algorithm is needed to match phaselets detect lost messages and detect communications channel failure Channel failure is defined by a sequence of lost messages where the length of the sequence is a design parameter In...

Page 754: ... the interrupt generated by an incoming message For both incoming and outgoing messages the important parameter is the jitter between when the time stamp is read and when the message begins to go out or to come in The quality of the crystal driving the clock and software sampling is not critical because of the compensation provided by the phase and frequency tracking algorithm unless it is desired...

Page 755: ...ith Channel asymmetry also contributes to this term The clock deviation computation is indicated in equation 10 15 as θi If two channels are used clock deviation is computed for both channels and then the average of absolute values is computed If GPS compensation is used then GPS clock compensation is subtracted from the clock deviation Startup error This term is used to estimate the initial start...

Page 756: ... Charging current compensation The basic premise for the operation of differential protection schemes in general and of the L90 line differential element in particular is that the sum of the currents entering the protected zone is zero In the case of a power system transmission line this is not entirely true because of the capacitive charging current of the line For short transmission lines the ch...

Page 757: ...ature of the line leads to the classical transmission line equations that can be solved for voltage and current profiles along the line What is needed for the compensation model is the effective positive and zero sequence capacitance seen at the line terminals Finally in some applications the effect of shunt reactors needs to be taken into account With very long lines shunt reactors can be install...

Page 758: ...ith a second redundant channel relays do not lose functionality at all if the second channel is live With one channel only relays have a five second time window If the channel is restored within this time it takes about two to three power cycles of valid PFLL calculations and if estimated error is still within margin to declare that PFLL is OK If the channel is restored later than five seconds PFL...

Page 759: ...teristics of differential elements can be shown in the complex plane The operating characteristics of the L90 are fundamentally dependant on the relative ratios of the local and remote current phasor magnitudes and the angles of IIoc Irem as shown in the Restraint Characteristics figure The main factors affecting the trip restraint decisions are Difference in angles real represents pure internal f...

Page 760: ...10 18 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL OPERATING CONDITION CHARACTERISTICS CHAPTER 10 THEORY OF OPERATION 10 Figure 10 7 Restraint characteristics ...

Page 761: ...nt value of 5 0 the equation for two terminal mode is used to calculate restraint as follows Eq 10 35 where σ 0 assuming a pure sine wave 10 2 3 Trip decision test The trip condition is shown Eq 10 36 The use of the CURRENT DIFF PICKUP CURRENT DIFF RESTRAINT 1 CURRENT DIFF RESTRAINT 2 and CURRENT DIFF BREAK PT settings are discussed in the Current Differential section of the Settings chapter The f...

Page 762: ...e elements It is well known that ground distance elements as per the principle of distance relaying can have limited accuracy during double line to ground faults In order to prevent maloperation in such cases the ground elements are blocked by an extra fault type comparator that utilizes the phase angle between the negative and zero sequence currents The phase distance elements use reactance and m...

Page 763: ... nature of signal distortions in the current and voltage signals digital pre filtering algorithms have been however designed and optimized separately for the current and voltage channels The current signals are pre filtered using an improved digital MIMIC filter The filter removes effectively the DC component s guaranteeing transient overshoot below 2 regardless of the initial magnitude and time c...

Page 764: ...r a lens as shown in the figure As explained in the Memory Polarization section the memory polarized mho characteristic has an excellent directional integrity built in Figure 10 9 Mho left and lens right characteristics 10 3 3 3 Non directional mho characteristics The non directional mho characteristic is achieved by checking the angle between AB phase element IA IB Z VA VB and VA VB IA IB ZREV BC...

Page 765: ...y checking the angle between AB phase element IA IB ZREV VA VB and IA IB ZREV BC phase element IB IC ZREV VB VC and IB IC ZREV CA phase element IC IA ZREV VC VA and IC IA ZREV A ground element IA ZREV I_0 K0 ZREV IG K0M ZREV VA and j I_0 or j I_2A ej 180 Θ B ground element IB ZREV I_0 K0 ZREV IG K0M ZREV VB and j I_0 or j I_2B ej 180 Θ C ground element IC ZREV I_0 K0 ZREV IG K0M ZREV VC and j I_0 ...

Page 766: ...ouble line to ground faults The fault type supervision is suppressed during open pole conditions For phase elements first voltages and then currents are checked to ensure permission to phase distance for any types of faults except SLG faults First the SLG fault type is determined by detecting one phase voltage depressed while two others are not by using the following equation SLG VA_LOW NOT VB_LOW...

Page 767: ... IA A B C ground element 3 I_0 0 05 I_1 The following tables summarize the characteristics of the distance elements Table 10 1 Directional mho phase distance functions Table 10 2 Directional mho ground distance functions Table 10 3 Directional quadrilateral phase distance functions Characteristic Comparator inputs Limit angle Variable mho I Z V V_1M COMP LIMIT Reactance I Z V I Z COMP LIMIT Direct...

Page 768: ... V_1M DIR COMP LIMIT removed when 3I_0 OC SUPV and I_2 CUTOFF Right Blinder I ZR V I ZR 90 Left Blinder I ZL V I ZL 90 Fault type I_0 I_2 50 removed during open pole conditions or when 3I_0 OC SUPV and I_2 CUTOFF Zero sequence I_0 ZD V_0 90 zones and higher only removed for zones 2 and higher during open pole conditions Characteristic Comparator inputs Limit angle Offset mho I Z V V I ZREV COMP LI...

Page 769: ... a polarizing signal The memory is established when the positive sequence voltage remains above 80 of its nominal value for five power system cycles The memory voltage is a two cycle old voltage Once established the memory is applied for the user specified time interval The memory timer is started when the voltage drops below 80 of nominal or when the user programmable condition is asserted to for...

Page 770: ...plies only to the reach defining comparators the mho reactance and blinder characteristics 10 3 6 Distance elements analysis 10 3 6 1 Description This subsection shows how to analyze the operation of the distance elements in steady states using the results of short circuit studies All quantities are secondary ohms volts and amperes Ground phase A and phase AB distance elements are analyzed Assume ...

Page 771: ...M 112 08 V 30 0 IA IB 7 39 A 109 1 10 3 6 2 Mho phase A to ground element before memory expires IA Z I_0 K0 Z IA K0M Z VA 103 33 V 3 9 VA_1M 64 71 V 0 0 IA_2 ZD 1 37 V 19 8 I_0 Z 19 11 V 19 8 I_0 ZD 1 37 V 19 8 Overcurrent supervision 3 I_0 4 09 A 3 A Mho difference angle 3 9 0 3 9 75 Reactance difference angle 3 9 19 8 23 7 75 Zero sequence directional difference angle 19 8 0 0 19 8 75 Negative s...

Page 772: ...pick up time out and operate 10 3 6 4 Mho AB phase element IA IB Z VA VB 88 65 V 78 7 VA VB _1M 112 08 V 30 0 IA IB Z 103 50 V 21 2 IA IB ZD 7 39 V 21 2 Overcurrent supervision IA IB 4 27 A 3 A Mho difference angle 78 7 30 0 108 7 75 Reactance difference angle 78 7 21 2 57 5 75 Directional difference angle 21 2 30 0 51 2 75 The mho comparator is not satisfied so the MHO AB phase element does not o...

Page 773: ...espond to faults behind the transformer The phase distance elements however can be developed so that both accurate reach and correct fault phase identification is retained for faults behind the power transformer as seen from the relaying point Without appropriate compensation the reach of the relay depends on a type of fault creating considerable difficulties in applying the relay The L90 provides...

Page 774: ...90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL PHASE DISTANCE APPLIED TO POWER TRANSFORMERS CHAPTER 10 THEORY OF OPERATION 10 Figure 10 12 Applications of the PHS DIST XF MR VOL CUR CONNECTION settings ...

Page 775: ...PTER 10 THEORY OF OPERATION PHASE DISTANCE APPLIED TO POWER TRANSFORMERS L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL 10 33 10 Table 10 9 Phase distance input signals for delta wye transformers ...

Page 776: ...10 34 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL PHASE DISTANCE APPLIED TO POWER TRANSFORMERS CHAPTER 10 THEORY OF OPERATION 10 ...

Page 777: ...set to Dy11 and the relay uses instead of a traditional IA IB for the AB phase distance element The current supervision pickup setting applies to the currents specified in the Current Transformation columns A distance zone originates at the location of the VTs regardless of the location of the CTs For information on settings see the Application of Settings chapter 10 4 2 Example Consider the syste...

Page 778: ...arent impedance Eq 10 42 This value is a correct measure of the distance from the VT location to the fault For relay location 2 this certainly includes the positive sequence impedance of the transformer Eq 10 43 Thus 0 127 Ω 90 0 05779 Ω 85 0 1847 Ω 88 4 primary side or 2 569 Ω 88 4 on the secondary side This example illustrates how the relay maintains correct reach for fault behind power transfor...

Page 779: ...single pole trip and reclose is required overall control within the relay is performed by the trip output element This element includes interfaces with pilot aided schemes the line pickup breaker control and breaker failure elements Single pole operations are based on use of the phase selector to identify the type of the fault to eliminate incorrect fault identification that can be made by distanc...

Page 780: ... A B and C This operator manual close request is also forwarded from breaker control to recloser which becomes disabled de asserting its Enabled output This output is transferred to trip output where it converts any input request for a single pole operation into a three pole operation At the recloser the AR1 BLK TIME MAN CLOSE timer is started The breaker closes and status monitoring contacts on t...

Page 781: ...g signals to protection elements are de asserted If the fault was transient then the reset time expires at the autorecloser and the AR FORCE 3 P TRIP and RIP outputs are de asserted returning all features to the state described at the beginning of this description If the fault was permanent appropriate protection elements detect this and place a trip request for the trip output element As the AR F...

Page 782: ... the zero sequence negative sequence and positive sequence voltages are used The pre fault values are subtracted prior to any calculations The pre fault quantities are captured and the calculations start when the disturbance detector 50DD operates When an open pole is declared the phase selector resets all its outputs operands and ignores any subsequent operations of the disturbance detector The p...

Page 783: ...OP FlexLogic operand is asserted or after delay defined by the PHASE SELECTOR RESET setting in the Trip Output element once the disturbance detector 50DD initially operated Figure 10 16 Phase selector logic PHASE SELECT CG Asserted when a phase C to ground fault is detected PHASE SELECT AB Asserted when a phase A to B fault is detected PHASE SELECT BC Asserted when a phase B to C fault is detected...

Page 784: ...selector data so a three pole operation can occur in a cross country fault condition Using four bit channels the relays share enough information about fault types seen from all the line terminals that local fault selector data can be rejected In addition in multiple bit systems the relays do not respond to non valid bit combinations making the protection system more immune to communication problem...

Page 785: ...ocal determination of fault type Trip output RX1 1 Any AG Fault Trip Phase A A N G 1 Any BG Fault Trip Phase B B N G 1 Any CG Fault Trip Phase C C N G 1 Any AB ABG BC BCG CA CAG 3P Unrecognized Trip Three Phases per local selection unrecognized and 3P A B C N G Remote data Local data Bit pattern received Remote determination of fault type Local determination of fault type Trip output RX1 0 Any AG ...

Page 786: ...a Local data Bit pattern received Remote determination of fault type Local determination of fault type Trip output RX1 RX2 1 0 AG BC BCG AG AB ABG CA CAG 3P Trip Phase A 0 1 BG CA CAG AG 1 1 CG AB ABG 3P Unrecognized AG 0 1 BG CA CAG BG AB ABG BC BCG 3P Trip Phase B 1 1 CG AB ABG 3P Unrecognized BG 1 0 AG BC BCG BG 1 1 CG AB ABG 3P Unrecognized CG BC BCG CA CAG Trip Phase C 1 0 AG BC BCG CG 0 1 BG...

Page 787: ...0 AG BC BCG AG AB ABG CA CAG 3P DCUB TRIP A 0 1 0 0 0 0 1 1 BG CA CAG AG 0 0 0 1 1 1 1 1 CG AB ABG 3P unrecognized AG 0 1 1 1 1 1 0 1 0 1 0 1 0 0 1 1 BG CA CAG BG AB ABG BC BCG 3P DCUB TRIP B 0 0 0 1 1 1 1 1 CG AB ABG 3P unrecognized BG 0 1 1 1 1 1 0 1 0 1 0 1 1 1 0 0 AG BC BCG BG 0 1 0 0 1 1 0 0 AG BC BCG CG DCUB TRIP C 0 1 0 0 0 0 1 1 BG CA CAG CG 0 0 0 1 1 1 1 1 CG AB ABG 3P unrecognized CG BC ...

Page 788: ...t type Bit pattern transmitted FlexLogic operands asserted TX1 TX2 TX3 TX4 TX1 STOP TX2 STOP TX3 STOP TX4 STOP AG 0 1 1 1 1 0 0 0 BG 1 0 1 1 0 1 0 0 CG 1 1 0 1 0 0 1 0 AB ABG BC BCG CA CAG 3P Unrecognized 1 1 1 0 0 0 0 1 Phase selector determination of fault type Bit pattern transmitted TX1 TX2 TX3 TX4 AG 1 0 0 0 BG 0 1 0 0 CG 0 0 1 0 AB ABG BC BCG CA CAG 3P Unrecognized 0 0 0 1 Remote data Local ...

Page 789: ...AG AB ABG CA CAG 3P Unrecognized 1 0 1 1 BG BG AB ABG BC BCG 3P Unrecognized DIR BLOCK TRIP B 0 1 1 1 AG BG 1 1 0 1 CG BG 1 1 1 0 MULTI P BG 1 1 0 1 CG CG BC BCG CA CAG 3P Unrecognized DIR BLOCK TRIP C 0 1 1 1 AG CG 1 0 1 1 BG CG 1 1 1 0 MULTI P CG 0 1 1 1 AG BC BCG DIR BLOCK TRIP 3P 1 0 1 1 BG CA CAG 1 1 0 1 CG AB ABG 1 1 1 0 MULTI P Unrecognized Remote data Local data Bit pattern received Remote...

Page 790: ...issive over reaching transfer trip permissive echo When used this feature echoes a reliable received permissive signal back to the originating terminal if the line end open condition is recognized by the line pickup scheme and the fault is not identified as a reverse fault by the zone 4 or the ground directional overcurrent function if used The permissive echo is programmed as a one shot logic The...

Page 791: ...reaching distance zone A given Pilot Scheme analyzes this zone for fault type identification if the Phase Selector asserts its Void flag the DUTT scheme uses Z1 all the other schemes use Z2 The schemes analyze all six fault loops of the zone to determine the fault type For example simultaneous forward AG and reverse BG faults can result in the Void indication The POTT scheme would analyze the Z2 r...

Page 792: ...ck up Ground Distance Zone 1 2 and 3 for an AG fault At T2 the phase selector determines the fault is type AG The reverse BG fault is likely to be ignored If a one bit channel is used terminal T1 trips three poles but terminal T2 trips phase A only which is undesirable See the table Table 10 34 One bit channel tripping If a two bit channel is used both terminals trip phase A only which is desired ...

Page 793: ...tion since they use the same equations applied to the same set of data The algorithm is executed for both two terminal and three terminal applications The three terminal algorithm executes at each terminal that has information from all three terminals If there is a communications failure on one channel it affects only one of the three terminals since there are fault phasors from all three terminal...

Page 794: ...s where upon receipt it is labeled as VREM1 X for channel 1 and VREM2 X for channel 2 The transmitted composite voltage signal is supervised by a VT fuse fail condition of the first source of 87L function During VT fuse fail conditions transmitted voltage is substituted with zero signaling to remote peers that multi ended fault location should be inhibited The impedance for fault location calculat...

Page 795: ...gment is selected as follows Eq 10 54 where Eq 10 55 A similar set of equations is applied to determine whether the fault is between the tap and the local terminal or between the tap and remote terminal 1 Next having all the data prepared the following universal equation is used to calculate the fault location Eq 10 56 For this equation two terminal applications the following equalities hold Eq 10...

Page 796: ...phase quantities before applying the equation above The following equations describe the voltage and current quantities for the three terminal applications where the subscript X denotes the line terminal of the faulted segment line TAP denotes the tap point the fault section and current flowing towards the fault from the tap point is the summation of currents of the two unfaulted line segments For...

Page 797: ...xample assumes 87L and fault locator sources are identi cal The following table shows the tap settings Table 10 38 Tap settings for multi ended example The following table shows the primary positive sequence impedances and length for the line Table 10 39 Line length and positive sequence impedance for multi ended example The figure shows how the three relays are connected Value Relay 1 Relay 2 Rel...

Page 798: ...rimary phase to ground voltage Value Relay 1 Relay 2 Relay 3 Local to tap 1 0219 sec ohms relay 1 to tap in relay 1 secondary ohms 6 0833 sec ohms relay 2 to tap in relay 2 secondary ohms 1 0707 sec ohms relay 3 to tap in relay 3 secondary ohms Remote 1 to tap 1 7520 sec ohms relay 2 to tap in relay 1 secondary ohms 3 5483 sec ohms relay 1 to tap in relay 2 secondary ohms 1 3626 sec ohms relay 1 t...

Page 799: ...s no fault between the tap and the remote 1 terminal and between the tap and remote 2 terminal Therefore the fault must be between the local terminal relay 2 and the tap Looking from relay 3 there is no fault between the tap and the remote 1 terminal and between the tap and the local terminal Therefore the fault must be between the remote 2 terminal relay 2 and the tap Note that the correct value ...

Page 800: ...200 A 8 999 pu 1000 A 5 6244 pu 1600 A 8 999 kA The data results in the following fault locations Relay 1 fault location 0 4173 pu or 0 4173 120 km 50 0704 km from its remote terminal 1 relay 2 Relay 2 fault location 0 4172 pu or 0 4172 120 km 50 07 km from local terminal relay 2 Relay 3 fault location 0 4173 pu or 0 4173 120 km 50 0704 km from its remote terminal 2 relay 2 The actual fault locati...

Page 801: ...ault location Figure 10 19 Equivalent system for fault location The following equations hold true for this equivalent system Eq 10 73 where m sought pu distance to fault Z positive sequence impedance of the line IF fault current flowing through the fault point The fault network during a fault can be decomposed into a pre fault and a pure fault network Therefore the fault current IF is calculated a...

Page 802: ... the entirely parallel line For ABC faults all three AB BC and CA loops are analyzed and the final result is selected based upon consistency of the results The element calculates the distance to the fault with m in miles or kilometers and the phases involved in the fault The relay allows locating faults from delta connected VTs If the FAULT REPORT 1 VT SUBSTITUTION setting is set to None and the V...

Page 803: ... location is performed based on the delta voltages and zero sequence voltage approximated based on the zero sequence current Eq 10 84 where ZSYS0 is the equivalent zero sequence impedance behind the relay as entered under the fault report setting menu Figure 10 20 Fault locator scheme Since the fault locator algorithm is based on the single end measurement method in three terminal configuration th...

Page 804: ...10 62 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL FAULT LOCATOR CHAPTER 10 THEORY OF OPERATION 10 ...

Page 805: ...argets item in the Online Window area below the list of devices It can take a few minutes for all devices to be read 2 Acknowledge any messages for unaccessible devices The Site Targets window opens when done Figure 11 1 Site Targets window 11 1 2 Data with Modbus Analyzer Use the Modbus Analyzer under Maintenance Modbus Analyzer to monitor the values of the UR device Use the Modbus memory map add...

Page 806: ...e UR device Setting To read a setting in the UR device Coil To read a command in the UR device of Element input or output to read An example is 1 for Contact Output 1 Selection examples demonstrate various ways to represent 0 Hex A decimal numbering system based on 16 possible values from 0 to 9 and A to F An example is 0x0000 Char A single unicode character such as C An example is 0 Int A 32 bit ...

Page 807: ...ts setting verification analog values injection or visual verification of setting file entries against relay settings schedule 4 Contact inputs and outputs verification This test can be conducted by direct change of state forcing or as part of the system functional testing 5 Visual inspection for any damage corrosion or dust 6 Event recorder file download with further events analysis 7 LED Test an...

Page 808: ...files CyberSentry security events are available in the following two files SECURITY_EVENTS CSV and SETTING_CHANGES LOG 11 3 1 1 Security events file The figure shows the content for the SECURITY_EVENTS CSV file Figure 11 3 Security events file Time Local time Activity The actual security event 1 Authentication Failed 2 User Lockout 3 FW Upgrade 4 FW Lock 5 Settings Lock 6 Settings Change this can ...

Page 809: ...nline device in the EnerVista software and select the Add Device to Offline Window option This copies the settings to the Offline Window area Any message about file repair usually means that settings were missing in the original file and have been added with default values to the new file 2 Make a copy of the settings file in the Offline Window area by right clicking the file and selecting Duplica...

Page 810: ...ng before conversion inspect the device backup file made before conversion In the example shown here settings have been reset to factory defaults and several settings are new in firmware version 7 6 under Settings System Setup Switches and Breakers Figure 11 6 Conversion report 5 Change settings in the new file for example by looking at the original file 6 Write the converted file to the device fo...

Page 811: ...it 5 Right click the copied device and select the Edit Device Properties option Make the changes for the new device 6 Send the file to new device by dragging and dropping it into the Online Window area Or right click and select the Write Settings to Device option 7 Update the remaining settings such as IP address 11 6 Compare settings Settings are comparable against default values and between two ...

Page 812: ...ct Compare with Device 2 In the window that opens enter a path file name at the bottom o f the window 3 Select the second device 4 Click the OK button The file generates and the differences are highlighted in red which is for the first device 11 7 Back up and restore settings Back up a copy of the in service settings for each commissioned UR device so as to revert to the commissioned settings afte...

Page 813: ...ine for example An Environment backup stores a list of sites and devices in the Online and Offline Window areas Settings files are not contained within the environment file If a settings file is moved renamed or deleted after the backup it is removed from the Offline Window during the restore To save a settings file in the URS format in EnerVista Online Window 1 In EnerVista connect to the device ...

Page 814: ...t click the device in the Online Window area 2 Select the Read ICD File option A window opens 3 Enter a path name for the file and click the Save button To save settings in the ICD format in EnerVista Offline Window 1 In EnerVista right click the device in the Offline Window area 2 Select the Create ICD File option Or select the Save As option and select the ICD option from drop down list You can ...

Page 815: ... file is rejected URS and IID procedures are outlined here To restore settings from a URS file 1 In EnerVista connect to the device in the Online Window area 2 Right click the urs file in the Offline Window area and select Add Device from File to locate a file and or drag and drop the file from the Offline Window area to the device in the Online Window area Figure 11 9 Restoring a URS settings fil...

Page 816: ...puter on the same subnetwork as the UR device open a SFTP client application such as WinSCP Note that TFTP cannot be used here 3 Use the device s IP address as the host name 4 If the device has the CyberSentry option use the User Name of Administrator or Engineer and the password programmed for the selected role The default password is ChangeMe1 without quotation marks 5 If the device does not hav...

Page 817: ...reinstalling the new versions A message can display about a version not being supported An example is when upgrading from version 7 12K to 7 4x The 7 12K entry is removed from the Offline Window area A message can display in the EnerVista software upon launch that a device from the environment was not recognized This means that a device is online and its firmware version conflicts with the softwar...

Page 818: ...alues of all settings that have been defaulted during conversion are not listed in the conversion report to find the value of a setting before conversion inspect the device backups made before conversion 4 In EnerVista navigate to Maintenance Update Firmware First select the boot file if applicable locating the bin file and proceed Restart the device the EnerVista software and refresh the order co...

Page 819: ... Product Setup Communications Network and record the IP address and subnet mask of the port s being used Record the gateway address under Default IPv4 Route 2 Turn off power to the unit Hot swapping of the front panel is not supported 3 For an enhanced front panel loosen the thumb screw and open slightly the front panel For a standard front panel lift up the black plastic latch on the right side o...

Page 820: ...oosen thumb screw on enhanced front panel to open Figure 11 13 Lift latch on standard front panel to open 4 With a Phillips screwdriver unscrew and remove the mounting bracket on the right side of the unit The bracket for the enhanced front panel looks similar to that for the graphical front panel but they are not the same ...

Page 821: ...11 Figure 11 14 Remove enhanced front panel mounting bracket on right side Figure 11 15 Remove standard front panel mounting bracket on right side 5 Open the front panel Unplug or unscrew the grey ground cable from the front panel Unplug the RJ45 connector from the CPU module in the second slot on the left ...

Page 822: ...AINTENANCE 11 Figure 11 16 Disconnected ground cable and CPU connector 6 Unscrew and remove the mounting bracket with the front panel from the left side Figure 11 17 Unscrew enhanced front panel mounting bracket on left side Figure 11 18 Unscrew standard front panel mounting bracket on left side ...

Page 823: ...l The front panel has been removed To install the graphical front panel 1 With power to the unit off screw the left mounting bracket to the outside of the relay The power supply module can remain in the first slot Figure 11 19 Attach mounting bracket to relay on left side no power supply module in first slot 2 Screw the right mounting bracket to the right side of the relay ...

Page 824: ...ront panel hinge to the left mounting bracket using the nuts provided Figure 11 21 Attach to left mounting bracket inside relay 4 Close the front panel without tightening the screw to the mounting bracket 5 Optionally remove the protective plastic film on the graphical front panel It is normally peeled off but also can be left on The graphical front panel has been installed but not connected ...

Page 825: ...odule by sliding the module out from the front of the relay See the next section for instructions Figure 11 22 Remove silver SFP connector shown here under LK1 label 2 At the front of the relay insert the new CPU module in the second slot The new CPU has two connection slots on the front Ensure that the RS485 connector and the black cover plate are not on the back of the CPU module before sliding ...

Page 826: ...es similar to the cover so it is difficult to see Figure 11 24 Connect graphical front panel to top connection on CPU module 4 Tighten the embedded screw on the right side of the graphical front panel to the mounting bracket Figure 11 25 Screw to attach graphical front panel to mounting bracket 5 At the back of the CPU module attach the new black cover plate to the back of the relay then connect t...

Page 827: ...r Settings Product Setup Installation 6 Update the EnerVista software to recognize the graphical front panel under Maintenance Change Front Panel This setting does not display for units already with a graphical front panel 11 11 Replace module This section outlines how to replace a module The relay being modular in design allows for the withdrawal and insertion of modules Replace modules only with...

Page 828: ...dingly for maximum safety 4 To properly insert a module ensure that the correct module type is inserted into the correct slot position The ejector inserter clips located at the top and at the bottom of each module must be in the disengaged position as the module is smoothly inserted into the slot Once the clips have cleared the raised edge of the chassis engage the clips simultaneously When the cl...

Page 829: ...e fourth screw is at the back end of the module on the opposite side from the clips beside the white electronics part see figure 7 Slide the metal cover away from the clips about 0 5 cm 1 8 inch and remove the cover 8 Unclip the black plastic holder that keeps the battery in place The plastic clips into the socket at the bottom on both sides pull the plastic away from the battery Use a flat head s...

Page 830: ... von Batterien Dieses Produkt beinhaltet eine Batterie die nicht als unsortierter städtischer Abfall in der europäischen Union entsorgt werden darf Beachten Sie die spezifischen Batterie informationen in der Produktdokumentation Die Batterie ist mit diesem Symbol gekennzeichnet welches auch Hinweise auf möglicherweise enthaltene Stoffe wie Kadmium Cd Blei Pb oder Quecksilber Hektogramm darstellt F...

Page 831: ...on può essere smaltita nei comuni contenitori per lo smaltimento rifiuti nell Unione Europea Controllate la documentazione del prodotto per le informazioni specifiche sulla batteria La batteria è contrassegnata con questo simbolo e può includere alcuni caratteri ad indicare la presenza di cadmio Cd piombo Pb oppure mercurio Hg Per il corretto smaltimento potete restituirli al vostro fornitore loca...

Page 832: ...ать буквы которые означают что батарея собержит кадмий Cd свинец Pb или ртуть Hg Для надлежащей утилизации по окончании срока эксплуатации пользователь должен возвратить батареи локальному поставщику или сдать в специальный пункт приема Подробности можно найти на веб сайте www recyclethis info 11 12 2 19 SK Zaobchádzanie s batériami Tento produkt obsahuje batériu s ktorou sa v Európskej únii nesmi...

Page 833: ...without return of the device to the factory The firmware and software can be upgraded without return of the device to the factory Fuses in the power supply module are not field replaceable Files can be requested for use by technical support staff for example the Service Report click the icon in the software or connect a USB drive to the graphical front panel or under Maintenance Retrieve File as o...

Page 834: ...s www gegridsolutions com multilin warranty htm 11 15 Storage Store the unit indoors in a cool dry place If possible store in the original packaging Follow the storage temperature range outlined in the Specifications 11 16 Disposal Other than the battery there are no special requirements for disposal of the unit at the end its service life For customers located in the European Union dispose of the...

Page 835: ...d ground fault 1 differential ground current magnitude 5794 RGF 1 Igr Mag Amps Restricted ground fault 1 restricted ground current magnitude 5796 RGF 2 Igd Mag Amps Restricted ground fault 2 differential ground current magnitude 5798 RGF 2 Igr Mag Amps Restricted ground fault 2 restricted ground current magnitude 5800 RGF 3 Igd Mag Amps Restricted ground fault 3 differential ground current magnitu...

Page 836: ...ource 1 neutral current angle 6164 SRC 1 Ig RMS Amps Source 1 ground current RMS 6166 SRC 1 Ig Mag Amps Source 1 ground current magnitude 6168 SRC 1 Ig Angle Degrees Source 1 ground current angle 6169 SRC 1 I_0 Mag Amps Source 1 zero sequence current magnitude 6171 SRC 1 I_0 Angle Degrees Source 1 zero sequence current angle 6172 SRC 1 I_1 Mag Amps Source 1 positive sequence current magnitude 6174...

Page 837: ...1 SRC 3 In Angle Degrees Source 3 neutral current angle 6292 SRC 3 Ig RMS Amps Source 3 ground current RMS 6294 SRC 3 Ig Mag Amps Source 3 ground current magnitude 6296 SRC 3 Ig Angle Degrees Source 3 ground current angle 6297 SRC 3 I_0 Mag Amps Source 3 zero sequence current magnitude 6299 SRC 3 I_0 Angle Degrees Source 3 zero sequence current angle 6300 SRC 3 I_1 Mag Amps Source 3 positive seque...

Page 838: ... Vab Mag Volts Source 1 phase AB voltage magnitude 6679 SRC 1 Vab Angle Degrees Source 1 phase AB voltage angle 6680 SRC 1 Vbc Mag Volts Source 1 phase BC voltage magnitude 6682 SRC 1 Vbc Angle Degrees Source 1 phase BC voltage angle 6683 SRC 1 Vca Mag Volts Source 1 phase CA voltage magnitude 6685 SRC 1 Vca Angle Degrees Source 1 phase CA voltage angle 6686 SRC 1 Vx RMS Volts Source 1 auxiliary v...

Page 839: ...Vbg Mag Volts Source 3 phase BG voltage magnitude 6795 SRC 3 Vbg Angle Degrees Source 3 phase BG voltage angle 6796 SRC 3 Vcg Mag Volts Source 3 phase CG voltage magnitude 6798 SRC 3 Vcg Angle Degrees Source 3 phase CG voltage angle 6799 SRC 3 Vab RMS Volts Source 3 phase AB voltage RMS 6801 SRC 3 Vbc RMS Volts Source 3 phase BC voltage RMS 6803 SRC 3 Vca RMS Volts Source 3 phase CA voltage RMS 68...

Page 840: ...sitive sequence voltage magnitude 6888 SRC 4 V_1 Angle Degrees Source 4 positive sequence voltage angle 6889 SRC 4 V_2 Mag Volts Source 4 negative sequence voltage magnitude 6891 SRC 4 V_2 Angle Degrees Source 4 negative sequence voltage angle 7168 SRC 1 P Watts Source 1 three phase real power 7170 SRC 1 Pa Watts Source 1 phase A real power 7172 SRC 1 Pb Watts Source 1 phase B real power 7174 SRC ...

Page 841: ...SRC 3 Phase A PF Source 3 phase A power factor 7258 SRC 3 Phase B PF Source 3 phase B power factor 7259 SRC 3 Phase C PF Source 3 phase C power factor 7264 SRC 4 P Watts Source 4 three phase real power 7266 SRC 4 Pa Watts Source 4 phase A real power 7268 SRC 4 Pb Watts Source 4 phase B real power 7270 SRC 4 Pc Watts Source 4 phase C real power 7272 SRC 4 Q Vars Source 4 three phase reactive power ...

Page 842: ...tts Source 2 real power demand 7704 SRC 2 Demand var Vars Source 2 reactive power demand 7706 SRC 2 Demand VA VA Source 2 apparent power demand 7712 SRC 3 Demand Ia Amps Source 3 phase A current demand 7714 SRC 3 Demand Ib Amps Source 3 phase B current demand 7716 SRC 3 Demand Ic Amps Source 3 phase C current demand 7718 SRC 3 Demand Watt Watts Source 3 real power demand 7720 SRC 3 Demand var Vars...

Page 843: ... Source 1 phase B voltage seventh harmonic 8096 SRC 1 Vb Harm 8 Source 1 phase B voltage eighth harmonic 8097 SRC 1 Vb Harm 9 Source 1 phase B voltage ninth harmonic 8098 SRC 1 Vb Harm 10 Source 1 phase B voltage tenth harmonic 8099 SRC 1 Vb Harm 11 Source 1 phase B voltage eleventh harmonic 8100 SRC 1 Vb Harm 12 Source 1 phase B voltage twelfth harmonic 8101 SRC 1 Vb Harm 13 Source 1 phase B volt...

Page 844: ...4 Source 2 phase A voltage fourth harmonic 8143 SRC 2 Va Harm 5 Source 2 phase A voltage fifth harmonic 8144 SRC 2 Va Harm 6 Source 2 phase A voltage sixth harmonic 8145 SRC 2 Va Harm 7 Source 2 phase A voltage seventh harmonic 8146 SRC 2 Va Harm 8 Source 2 phase A voltage eighth harmonic 8147 SRC 2 Va Harm 9 Source 2 phase A voltage ninth harmonic 8148 SRC 2 Va Harm 10 Source 2 phase A voltage te...

Page 845: ...se C voltage total harmonic distortion THD 8190 SRC 2 Vc Harm 2 Source 2 phase C voltage second harmonic 8191 SRC 2 Vc Harm 3 Source 2 phase C voltage third harmonic 8192 SRC 2 Vc Harm 4 Source 2 phase C voltage fourth harmonic 8193 SRC 2 Vc Harm 5 Source 2 phase C voltage fifth harmonic 8194 SRC 2 Vc Harm 6 Source 2 phase C voltage sixth harmonic 8195 SRC 2 Vc Harm 7 Source 2 phase C voltage seve...

Page 846: ...voltage twenty third harmonic 8237 SRC 3 Va Harm 24 Source 3 phase A voltage twenty fourth harmonic 8238 SRC 3 Va Harm 25 Source 3 phase A voltage twenty fifth harmonic 8239 SRC 3 Vb THD Source 3 phase B voltage total harmonic distortion THD 8240 SRC 3 Vb Harm 2 Source 3 phase B voltage second harmonic 8241 SRC 3 Vb Harm 3 Source 3 phase B voltage third harmonic 8242 SRC 3 Vb Harm 4 Source 3 phase...

Page 847: ...se C voltage twentieth harmonic 8284 SRC 3 Vc Harm 21 Source 3 phase C voltage twenty first harmonic 8285 SRC 3 Vc Harm 22 Source 3 phase C voltage twenty second harmonic 8286 SRC 3 Vc Harm 23 Source 3 phase C voltage twenty third harmonic 8287 SRC 3 Vc Harm 24 Source 3 phase C voltage twenty fourth harmonic 8288 SRC 3 Vc Harm 25 Source 3 phase C voltage twenty fifth harmonic 8289 SRC 4 Va THD Sou...

Page 848: ...hase B voltage seventeenth harmonic 8331 SRC 4 Vb Harm 18 Source 4 phase B voltage eighteenth harmonic 8332 SRC 4 Vb Harm 19 Source 4 phase B voltage nineteenth harmonic 8333 SRC 4 Vb Harm 20 Source 4 phase B voltage twentieth harmonic 8334 SRC 4 Vb Harm 21 Source 4 phase B voltage twenty first harmonic 8335 SRC 4 Vb Harm 22 Source 4 phase B voltage twenty second harmonic 8336 SRC 4 Vb Harm 23 Sou...

Page 849: ...agnitude 9026 Prefault Ia Ang 1 Degrees Fault 1 pre fault phase A current angle 9027 Prefault Ib Mag 1 Amps Fault 1 pre fault phase B current magnitude 9029 Prefault Ib Ang 1 Degrees Fault 1 pre fault phase B current angle 9030 Prefault Ic Mag 1 Amps Fault 1 pre fault phase C current magnitude 9032 Prefault Ic Ang 1 Degrees Fault 1 pre fault phase C current angle 9033 Prefault Va Mag 1 Volts Fault...

Page 850: ...angle 9375 Terminal 2 IB Angle Degrees Remote terminal 2 current phase B angle 9376 Terminal 2 IC Angle Degrees Remote terminal 2 current phase C angle 9377 Diff Curr IA Angle Degrees Differential current phase A angle 9378 Diff Curr IB Angle Degrees Differential current phase B angle 9379 Diff Curr IC Angle Degrees Differential current phase C angle 9380 Op Square Curr IA Amps Phase A operating s...

Page 851: ... Phasor measurement unit 1 zero sequence voltage angle 9602 PMU 1 Ia Mag Amps Phasor measurement unit 1 phase A current magnitude 9604 PMU 1 Ia Angle Degrees Phasor measurement unit 1 phase A current angle 9605 PMU 1 Ib Mag Amps Phasor measurement unit 1 phase B current magnitude 9607 PMU 1 Ib Angle Degrees Phasor measurement unit 1 phase B current angle 9608 PMU 1 Ic Mag Amps Phasor measurement u...

Page 852: ... Source 1 phase B current fifth harmonic 10278 SRC 1 Ib Harm 6 Source 1 phase B current sixth harmonic 10279 SRC 1 Ib Harm 7 Source 1 phase B current seventh harmonic 10280 SRC 1 Ib Harm 8 Source 1 phase B current eighth harmonic 10281 SRC 1 Ib Harm 9 Source 1 phase B current ninth harmonic 10282 SRC 1 Ib Harm 10 Source 1 phase B current tenth harmonic 10283 SRC 1 Ib Harm 11 Source 1 phase B curre...

Page 853: ... Source 2 phase A current second harmonic 10341 SRC 2 Ia Harm 3 Source 2 phase A current third harmonic 10342 SRC 2 Ia Harm 4 Source 2 phase A current fourth harmonic 10343 SRC 2 Ia Harm 5 Source 2 phase A current fifth harmonic 10344 SRC 2 Ia Harm 6 Source 2 phase A current sixth harmonic 10345 SRC 2 Ia Harm 7 Source 2 phase A current seventh harmonic 10346 SRC 2 Ia Harm 8 Source 2 phase A curren...

Page 854: ... B current twenty fourth harmonic 10396 SRC 2 Ib Harm 25 Source 2 phase B current twenty fifth harmonic 10405 SRC 2 Ic THD Source 2 phase C current total harmonic distortion 10406 SRC 2 Ic Harm 2 Source 2 phase C current second harmonic 10407 SRC 2 Ic Harm 3 Source 2 phase C current third harmonic 10408 SRC 2 Ic Harm 4 Source 2 phase C current fourth harmonic 10409 SRC 2 Ic Harm 5 Source 2 phase C...

Page 855: ...current twenty first harmonic 10459 SRC 3 Ia Harm 22 Source 3 phase A current twenty second harmonic 10460 SRC 3 Ia Harm 23 Source 3 phase A current twenty third harmonic 10461 SRC 3 Ia Harm 24 Source 3 phase A current twenty fourth harmonic 10462 SRC 3 Ia Harm 25 Source 3 phase A current twenty fifth harmonic 10471 SRC 3 Ib THD Source 3 phase B current total harmonic distortion 10472 SRC 3 Ib Har...

Page 856: ...se C current eighteenth harmonic 10522 SRC 3 Ic Harm 19 Source 3 phase C current nineteenth harmonic 10523 SRC 3 Ic Harm 20 Source 3 phase C current twentieth harmonic 10524 SRC 3 Ic Harm 21 Source 3 phase C current twenty first harmonic 10525 SRC 3 Ic Harm 22 Source 3 phase C current twenty second harmonic 10526 SRC 3 Ic Harm 23 Source 3 phase C current twenty third harmonic 10527 SRC 3 Ic Harm 2...

Page 857: ...hase B current fifteenth harmonic 10585 SRC 4 Ib Harm 16 Source 4 phase B current sixteenth harmonic 10586 SRC 4 Ib Harm 17 Source 4 phase B current seventeenth harmonic 10587 SRC 4 Ib Harm 18 Source 4 phase B current eighteenth harmonic 10588 SRC 4 Ib Harm 19 Source 4 phase B current nineteenth harmonic 10589 SRC 4 Ib Harm 20 Source 4 phase B current twentieth harmonic 10590 SRC 4 Ib Harm 21 Sour...

Page 858: ...Delta Phs Degrees Synchrocheck 1 delta_phase 10863 Synchchk 1 SSCP DPh Degrees Synchrocheck 1 _synchscope 10864 Synchchk 2 Delta V Volts Synchrocheck 2 delta voltage 10866 Synchchk 2 Delta Phs Degrees Synchrocheck 2 delta phase 10867 Synchchk 2 SSCP DPh Degrees Synchrocheck 2 synchscope 10868 Synchchk 2 Delta F Hz Synchrocheck 2 delta frequency 10869 Synchchk 2 V1 Mag Volts Synchrocheck 2 V1 mag 1...

Page 859: ...Delta Phs Degrees Synchrocheck 5 delta_phase 10927 Synchchk 5 SSCP DPh Degrees Synchrocheck 5 _synchscope 10928 Synchchk 6 Delta V Volts Synchrocheck 6 delta voltage 10930 Synchchk 6 Delta Phs Degrees Synchrocheck 6 delta phase 10931 Synchchk 6 SSCP DPh Degrees Synchrocheck 6 synchscope 10932 Synchchk 6 Delta F Hz Synchrocheck 6 delta frequency 10933 Synchchk 6 V1 Mag Volts Synchrocheck 6 V1 mag 1...

Page 860: ...ynchrocheck 9 V2_angle 10990 Synchchk 9 Delta Phs Degrees Synchrocheck 9 delta_phase 10991 Synchchk 9 SSCP DPh Degrees Synchrocheck 9 _synchscope 10992 Synchchk 10Delta V Volts Synchrocheck 10 delta voltage 10994 Synchchk 10Delta Phs Degrees Synchrocheck 10 delta phase 10995 Synchchk 10SSCP DPh Degrees Synchrocheck 10 synchscope 10996 Synchchk 10Delta F Hz Synchrocheck 10 delta frequency 10997 Syn...

Page 861: ...13508 DCmA Ip 3 mA DCmA input 3 actual value 13510 DCmA Ip 4 mA DCmA input 4 actual value 13512 DCmA Ip 5 mA DCmA input 5 actual value 13514 DCmA Ip 6 mA DCmA input 6 actual value 13516 DCmA Ip 7 mA DCmA input 7 actual value 13518 DCmA Ip 8 mA DCmA input 8 actual value 13520 DCmA Ip 9 mA DCmA input 9 actual value 13522 DCmA Ip 10 mA DCmA input 10 actual value 13524 DCmA Ip 11 mA DCmA input 11 actu...

Page 862: ...lue 13580 RTD Ip 29 RTD input 29 actual value 13581 RTD Ip 30 RTD input 30 actual value 13582 RTD Ip 31 RTD input 31 actual value 13583 RTD Ip 32 RTD input 32 actual value 13584 RTD Ip 33 RTD input 33 actual value 13585 RTD Ip 34 RTD input 34 actual value 13586 RTD Ip 35 RTD input 35 actual value 13587 RTD Ip 36 RTD input 36 actual value 13588 RTD Ip 37 RTD input 37 actual value 13589 RTD Ip 38 RT...

Page 863: ...1 Volts VTFF 1 V0 3rd Harmonic 41140 V0 3rd Harmonic 2 Volts VTFF 2 V0 3rd Harmonic 41142 V0 3rd Harmonic 3 Volts VTFF 3 V0 3rd Harmonic 41144 V0 3rd Harmonic 4 Volts VTFF 4 V0 3rd Harmonic 42400 Volts Per Hertz 1 pu Volts per hertz 1 actual value 42401 Volts Per Hertz 2 pu Volts per hertz 2 actual value 45584 RxGOOSE Analog 1 RxGOOSE analog input 1 45586 RxGOOSE Analog 2 RxGOOSE analog input 2 45...

Page 864: ...5 RxGOOSE analog input 25 45634 RxGOOSE Analog 26 RxGOOSE analog input 26 45636 RxGOOSE Analog 27 RxGOOSE analog input 27 45638 RxGOOSE Analog 28 RxGOOSE analog input 28 45640 RxGOOSE Analog 29 RxGOOSE analog input 29 45642 RxGOOSE Analog 30 RxGOOSE analog input 30 45644 RxGOOSE Analog 31 RxGOOSE analog input 31 45646 RxGOOSE Analog 32 RxGOOSE analog input 32 61439 PMU Num Triggers Phasor measurem...

Page 865: ...our RADIUS server IP address An example is bind_address 10 14 61 109 Text editor software that supports direct editing and saving of UNIX text encodings and line breaks such as EditPad Lite is needed for this editing 3 In the users conf file in the Path_to_Radius etc raddb folder add the following text to configure a user Tester with an Administrator role Tester User Password testpw GE PDC USER Ro...

Page 866: ...art_radiusd_debug bat 8 Set up the RADIUS parameters on the UR as follows 8 1 If logging in select Device for the Authentication Type and use Administrator for the User Name The default password is ChangeMe1 8 2 Access Settings Product Setup Security Configure the IP address and ports for the RADIUS server Leave the GE vendor ID field at the default of 2910 Update the RADIUS shared secret as speci...

Page 867: ...ntly with the command line interface It does not support concurrent commands It has limited functionality with CyberSentry It does not interface with UR Engineer It does not work when EnerVista UR Setup security is enabled meaning when login is required Command syntax is as follows Options enclosed in are optional Values enclosed in are replaced with your own values Application is replaced with th...

Page 868: ...dow SetupCLI h Display help It displays the content outline here SetupCLI Application start c s Launch application with name Application To start in client mode which is the graphical user interface include option c Before use the software must be idle without any windows open Any activity or open windows can cause unexpected behavior When in client mode do not use Launchpad s Site Management feat...

Page 869: ...tings from device device and save them to the urs file File The File must not already exist The default path to the output file is C Users Public Public Documents GE Power Management URPC Data Example SetupCLI URPC getsettings d C30 f C30 Markham urs Example of a batch file to retrieve a settings file SetupCLI URPC start SetupCLI URPC getsettings d demoDevice f C example urs SetupCLI URPC exit Exa...

Page 870: ...t URPC Data Setting Name Group Module Item Value 1 Default Message Timeout 1 1 1 299 s 2 Default Message Timeout 1 1 1 300 s 3 Flash Message Time 1 1 1 0 9 s 4 Flash Message Time 1 1 1 1 0 s SetupCLI Application inservice d device n s Put the device in service Include option n to take the device out of service Example SetupCLI URPC inservice d C30 SetupCLI Application reboot d device s Reboot the ...

Page 871: ... using a device IP address to retrieve its settings file SetupCLI URPC start SetupCLI URPC adddevice I 192 168 140 113 S 113 P 502 SetupCLI URPC getsettings d DEV SETUP_CLI f C example urs SetupCLI URPC exit After connecting the device using IP address the device name DEV SETUP_CLI is used to identify this device in getsettings command Example of a batch file using a device IP address to retrieve ...

Page 872: ...C 6 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL COMMAND LINE INTERFACE APPENDIX C COMMAND LINE INTERFACE C ...

Page 873: ...ory The tables outline the releases and revision history of this document Table D 1 Revision history English Manual P N L90 revision Release date ECO 1601 0081 A1 1 0x 04 November 1998 N A 1601 0081 A2 1 0x 09 December 1998 URL 039 1601 0081 A3 1 5x 25 June 1999 URL 051 1601 0081 A4 1 5x 10 August 1999 URL 055 1601 0081 A5 1 5x 02 September 1999 URL 057 1601 0081 A6 2 0x 17 December 1999 URL 063 1...

Page 874: ... 4 6x 15 February 2005 URX 176 1601 0081 L1 4 8x 05 August 2005 URX 202 1601 0081 M1 4 9x 15 December 2005 URX 208 1601 0081 M2 4 9x 27 February 2006 URX 214 1601 0081 N1 5 0x 31 March 2006 URX 217 1601 0081 N2 5 0x 26 May 2006 URX 220 1601 0081 P1 5 2x 23 October 2006 URX 230 1601 0081 P2 5 2x 24 January 2007 URX 232 1601 0081 R1 5 4x 26 June 2007 URX 242 1601 0081 R2 5 4x 31 August 2007 URX 246 ...

Page 875: ... per product table Modbus memory map Updated Current CT Settings number from 4 to 6 in FlexLogic operands table settings features per product table and Modbus memory map Updated Ground Instantaneous number from 8 to 12 in FlexLogic operands table settings features per product table Modbus memory map Updated Ground Time Overcurrent number from 4 to 6 in FlexLogic operands table settings features pe...

Page 876: ...cs and THD Metering content to description specifications actual values FlexElements table Modbus memory map IMD table Added Source Current THD and Harmonics content to specifications actual values Modbus memory map Added Compensated Overvoltage content to product description specifications FlexLogic operands table settings features per product table Modbus memory map IMD tables Updated number of ...

Page 877: ...APPENDIX D MISCELLANEOUS REVISION HISTORY L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL D 5 D 11 2 Added Retrieve Files section C Added Command Line Interface appendix Page Description ...

Page 878: ...D 6 L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL REVISION HISTORY APPENDIX D MISCELLANEOUS D ...

Page 879: ...COMM Communications COMP Compensated Comparison CONN Connection CONT Continuous Contact CO ORD Coordination CPU Central Processing Unit CRC Cyclic Redundancy Code Check CRL Certificate Revocation List CRT CRNT Current CSA Canadian Standards Association CT Current Transformer CVT Capacitive Voltage Transformer D A Digital to Analog DC dc Direct Current DCE Data Communications Equipment DCS Distribu...

Page 880: ...iode LEO Line End Open LFT BLD Left Blinder LOOP Loopback LPU Line Pickup LRA Locked Rotor Current LTC Load Tap Changer LV Low Voltage M Machine M2M Machine to Machine mA MilliAmpere MAG Magnitude MAN Manual Manually MAX Maximum MIC Model Implementation Conformance MIN Minimum Minutes MMI Man Machine Interface MMS Manufacturing Message Specification MRT Minimum Response Time MSG Message MTA Maximu...

Page 881: ...cs SUPN Supervision SUPV Supervise Supervision SV Supervision Service SYNC Synchrocheck SYNCHCHK Synchrocheck T Time transformer TC Thermal Capacity TCP Transmission Control Protocol TCU Thermal Capacity Used TD MULT Time Dial Multiplier TEMP Temperature TFTP Trivial File Transfer Protocol THD Total Harmonic Distortion TMR Timer TOC Time Overcurrent TOV Time Overvoltage TRANS Transient TRANSF Tran...

Page 882: ...iv L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL ABBREVIATIONS ...

Page 883: ...user account 5 15 command to force logoff 7 6 role for CyberSentry 2 9 Aggregator actual values 6 26 settings 5 184 Aggregator error message 7 11 Alarm LEDs 5 124 Alarms acknowledge 4 35 add 4 35 5 37 messages 7 7 overview 4 32 reset 4 35 AND gate explained 4 84 Annunciator editor 4 35 ANSI device numbers 2 2 Apparent power 6 19 specifications 2 43 Application examples breaker trip circuit integri...

Page 884: ...reaker failure description 5 294 determination 5 294 FlexLogic operands 5 191 logic diagram 5 298 5 299 main path sequence 5 295 settings 5 292 5 296 specifications 2 38 Breaker flashover FlexLogic operands 5 191 logic diagram 5 360 settings 5 356 specifications 2 38 Breaker restrike FlexLogic operands 5 192 logic diagram 5 363 settings 5 361 specifications 2 38 Breaker and a half scheme 5 6 Brigh...

Page 885: ... 6 4 explained 5 414 FlexLogic operands 5 200 settings 5 413 specifications 2 44 thresholds 5 413 wet and dry connections 3 22 Contact outputs actual values 6 5 explained 5 416 FlexLogic operands 5 200 settings 5 416 Continuous monitor FlexLogic operands 5 192 logic diagram 5 364 settings 5 363 Control elements 5 324 Control power description 3 13 specifications 2 47 Control pushbuttons FlexLogic ...

Page 886: ... 1 2 4 78 Device overview 11 1 Device setup 3 61 Diagnostic alarm error 7 9 Diagnostic failure error 7 8 Dielectric strength 3 13 Differential current 2 33 5 217 current FlexAnalogs A 16 stub bus 5 221 trip 5 318 Digital counters actual values 6 8 FlexLogic operands 5 193 logic diagram 5 352 settings 5 350 Digital elements application example 5 349 FlexLogic operands 5 193 logic diagram 5 348 sett...

Page 887: ... 51 restart relay 5 1 Engineer command to force user logoff 7 6 create logic diagram 4 63 Error messages 4 71 Warning messages 4 72 Engineer toolbar 4 82 Enhanced front panel FlexLogic 5 190 interface 4 14 keypad 4 38 labels 4 44 LEDs 4 40 5 124 navigation 4 51 order codes 2 11 pushbuttons 5 127 specifications 2 41 use change setting 4 53 Environment backup 11 9 Equations definite time curve 5 261...

Page 888: ...Analogs A 29 FlexLogic operands 5 194 hysteresis 5 211 logic diagram 5 211 pickup 5 211 settings 5 209 specifications 2 41 FlexLogic create logic diagram with Engineer 4 63 edit with equation editor 5 209 equation editor 5 209 equation example 5 327 error messages 7 8 evaluation 5 204 example 5 204 gate characteristics 5 202 lock equations 4 9 lock equations to serial number 4 11 operands 5 189 op...

Page 889: ...ledge reset 4 35 alarm setup 5 37 annunciator editor 4 35 date and time 5 31 explained 4 18 FlexLogic 5 190 Home page configuration 5 29 interface 4 16 labels 4 50 LEDs 4 43 5 124 Metering Editor 4 36 navigation 4 52 navigation keys 4 39 no display 5 32 order codes 2 11 phasor diagram 4 58 5 33 plastic protective film 11 20 pushbutton testing 7 3 pushbuttons 5 127 pushbuttons 9 to 16 4 30 settings...

Page 890: ...1 8 import preferences 11 9 Import settings file 3 65 Import settings from SCD or CID file 11 12 In service indicator 7 7 In Service LED 3 49 Incompatible device order codes or versions 11 14 Incompatible hardware error 7 8 Inputs AC current specifications 2 44 AC currents 5 137 AC voltage 5 138 AC voltage specifications 2 44 contact input specifications 2 44 contact inputs 5 413 5 431 DCmA input ...

Page 891: ...tem 5 26 Loop actual values 6 27 Loop filter block diagram 10 11 Loopback settings 5 432 Loopback test 2 7 Lost password 5 9 Low voltage fault 8 13 M MAC address actual values 6 34 examples 5 44 RxGOOSE 5 72 settings for redundancy 5 47 TxGOOSE 5 69 Maintenance actual values 6 33 alert to replace battery 7 9 battery replacement 11 24 cleaning 2 53 commands 7 3 module replacement 11 23 upgrade or d...

Page 892: ...5 logic diagram 5 269 settings 5 268 specifications 2 34 Non volatile latches FlexLogic operands 5 194 settings 5 214 specifications 2 41 NOR gate explained 4 84 NOT gate explained 4 84 O Obtain list of port numbers 5 46 One shot commands menu PMU 7 4 error compiling in Engineer 4 71 FlexLogic operators 5 203 Open pole detector FlexLogic operands 5 195 logic diagrams 5 369 settings 5 367 specifica...

Page 893: ...FlexLogic operands 5 196 logic diagram 5 235 OP scheme 5 234 settings 5 226 specifications 2 31 Phase IOC FlexLogic operands 5 196 logic diagram 5 264 settings 5 263 specifications 2 34 Phase overvoltage FlexLogic operands 5 196 logic diagram 5 305 settings 5 304 specifications 2 36 Phase rotation 5 138 Phase select FlexLogic operands 5 196 logic diagram 10 41 Phase TOC FlexLogic operands 5 197 lo...

Page 894: ...EC 61850 5 62 import file 11 9 Preserve custom attributes when importing SCD CID files 11 9 Print front panel labels 4 44 4 77 Process bus order codes for compatible URs 2 11 overview 3 16 Product information actual values 6 34 Device Connectivity Report in Engineer 4 78 firmware revision 6 34 Programmed mode 3 49 Protection elements 5 4 Protection features 2 3 Protection Summary interface 3 63 4 ...

Page 895: ...82 specifications 2 34 Revision history D 1 RF immunity specifications 2 52 RFI conducted specifications 2 52 R GOOSE description 5 66 RJ 45 2 11 3 11 RMS voltage specifications 2 43 Roles for login 2 9 Rolling demand 5 121 Routable GOOSE 5 66 RS232 baud rate 5 43 configuration 3 63 specifications 2 48 wiring 3 29 RS422 configuration 3 39 timing 3 41 two channel application 3 39 with fiber interfa...

Page 896: ...1 5 write to device with Modbus Analyzer 11 1 Settings file 5 60 description 4 1 import 3 65 takes relay out of service when loaded 4 2 traceability 4 12 transfer with USB stick 4 16 Settings password 4 61 5 11 Settings templates description 4 5 edit 4 6 enable 4 5 password protection 4 7 remove 4 9 view 4 7 SFP error messages 7 12 explained 3 10 module fail message 7 12 photo 11 21 Signal loss de...

Page 897: ...ssages 7 7 TARGET setting 5 5 Targets menu 7 7 Targets overview by device 11 1 TBD 11 9 TCP port number for web access 5 100 Technical support 1 2 files 1 2 11 3 Temperature FlexLogic monitor operand 5 202 monitor 7 11 operating and storage 2 51 Test voltages 3 13 Testing channel 5 432 Communications with loopback 5 432 force contact inputs 5 431 force contact outputs 5 431 lamp test 7 3 LEDs 7 3 ...

Page 898: ...s 5 340 specifications 2 37 Undervoltage auxiliary 2 36 characteristics 5 302 phase 2 36 5 303 settings 5 303 Unexpected restart error 7 11 Uninstall 11 29 Unit not programmed 5 135 Unit not programmed message 7 8 Unpacking the relay 3 1 Update SCL files prompt 4 70 Update settings with Convert Device Settings 11 5 Updates device not recognized 11 13 firmware 11 13 FPGA 11 15 instruction manual 3 ...

Page 899: ...lexLogic operands 5 198 logic diagram 5 367 settings 5 366 VT inputs 3 14 5 8 5 138 VT wiring 3 15 VTFF 5 366 A 29 W Warning messages in Engineer 4 72 Warning symbol in Offline Window 4 70 Warning firmware upload not supported 11 14 Warranty D 1 Watt hour specifications 2 43 Watt hours 6 20 Wattmetric zero sequence directional actual values 6 25 FlexLogic operands 5 200 logic diagram 5 279 setting...

Page 900: ...xviii L90 LINE CURRENT DIFFERENTIAL SYSTEM INSTRUCTION MANUAL INDEX ...

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