instruction manual gard 8000 distance relay module · 2017-05-23 · april 1, 2010 i 973.334.3100...

April 1, 2010 i 973.334.3100

INSTRUCTION MANUAL

GARD 8000 DISTANCE RELAY MODULE

(This manual should always be used in conjunction with the GARD 8000 System Instructional Manual)

NOTICE

GARD 8000 Distance Relay RFL Electronics Inc.

The information in this manual is proprietary and confidential to RFL Electronics Inc. Any reproduction or distribution of this manual, in whole or part, is expressly prohibited, unless written permission is given by RFL Electronics Inc. This manual has been compiled and checked for accuracy. The information in this manual does not constitute a warranty of performance. RFL Electronics Inc. reserves the right to revise this manual and make changes to its contents from time to time. We assume no liability for losses incurred as a result of out-of-date or incorrect information contained in this manual.

RFL Electronics Inc. 353 Powerville Road Boonton Twp., NJ 07005-9151 USA

Tel: 973.334.3100 Fax: 973.334.3863 Email: [email protected] www.rflelect.com

Publication Number MC8000DIS Printed in U.S.A.

April 1, 2010

mailto:[email protected]

http://www.rflelect.com/


WARRANTY The GARD 8000 Distance Relay comes with a ten-year warranty from date of shipment for replacement of any part, which fails during normal operation. RFL will repair or, at its option, replace components that prove to be defective at no cost to the Customer. All equipment returned to RFL Electronics Inc. must have an RMA (Return Material Authorization) number, obtained by calling the RFL Customer Service Department. A defective part should be returned to the factory, shipping charges prepaid, for repair or replacement FOB Boonton, N.J. RFL Electronics Inc. is not responsible for warranty of peripherals, such as printers and external computers. The warranty for such devices is as stated by the original equipment manufacturer. If you have purchased peripheral equipment not manufactured by RFL, follow the written instructions supplied with that equipment for warranty information and how to obtain service.

WARRANTY STATEMENT The GARD 8000 product family is warranted against defects in material and workmanship for ten years from the date of shipment. During the warranty period, RFL will repair or, at its option, replace components that prove to be defective at no cost to the customer, except the one-way shipping cost of the failed assembly to the RFL Customer Service facility in Boonton, New Jersey. RFL warrants product repair from one-year from the date of repair or the balance of the original warranty, whichever is longer. This warranty does not apply if the equipment has been damaged by accident, neglect, misuse, or causes other than performed or authorized by RFL Electronics Inc. This warranty specifically excludes damage incurred in shipment to or from RFL. In the event an item is received in damaged condition, the carrier should be notified immediately. All claims for such damage should be filed with the carrier.

NOTE

If you do not intend to use the product immediately, it is recommended that it be opened immediately after receiving and inspected for proper operation and signs of impact damage. This warranty is in lieu of all other warranties, whether expressed, implied or statutory, including but not limited to implied warranties of merchantability and fitness for a particular purpose. In no event shall RFL be liable, whether in contract, in tort, or on any other basis, for any damages sustained by the customer or any other person arising from or related to loss of use, failure or interruption in the operation of any products, or delay in maintenance or for incidental, consequential, indirect, or special damages or liabilities, or for loss of revenue, loss of business, or other financial loss arising out of or in connection with the sale, lease, maintenance, use, performance, failure, or interruption of the products.

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Table of Contents TABLE OF CONTENTS ......................................................................................................................................... III TABLE OF FIGURES..............................................................................................................................................V LIST OF TABLES ..................................................................................................................................................VII WARNING LABELS AND SAFETY SUMMARY ....................................................................................................IX SECTION 1. PRODUCT INFORMATION ............................................................................................................1-1 SECTION 2. GENERAL DESCRIPTION AND OVERVIEW ...............................................................................2-1

2.1 DESCRIPTION ............................................................................................................................................................................... 2-1 2.2 GENERAL OVERVIEW ................................................................................................................................................................ 2-1

SECTION 3. SYSTEM SPECIFICATIONS ..........................................................................................................3-1 SECTION 4. DISTANCE RELAY OPERATING TIMES.......................................................................................4-1 SECTION 5. STANDARDS AND TYPE TESTS ..................................................................................................5-1 SECTION 6. CONFIGURATION ..........................................................................................................................6-1

6.1 SYSTEM CONFIGURATION OVERVIEW.................................................................................................................................. 6-1 6.2 HARDWARE CONFIGURATION................................................................................................................................................. 6-1 6.3 LOGIC SIGNALS AVAILABLE FROM THE DISTANCE PROTECTION MODULE............................................................... 6-8

SECTION 7. DISTANCE RELAY SETTINGS ......................................................................................................7-1 7.1 GENERAL SETTINGS................................................................................................................................................................... 7-1 7.2 LINE PROTECTION SYSTEM SETTINGS .................................................................................................................................. 7-2 7.3 DISTANCE ELEMENTS................................................................................................................................................................ 7-7 7.4 CURRENT ELEMENTS............................................................................................................................................................... 7-15 7.5 RECLOSER AND SYNC CHECK ............................................................................................................................................... 7-24 7.6 BREAKER FAILURE................................................................................................................................................................... 7-27 7.7 VOLTAGE ELEMENTS............................................................................................................................................................... 7-28 7.8 FAULT RECORDER (DFR)......................................................................................................................................................... 7-30 7.9 OSCILLOGRAPHY MASK.......................................................................................................................................................... 7-31 7.10 SOE MASK ................................................................................................................................................................................. 7-33

SECTION 8. DISTANCE RELAY SETTING EXAMPLES ....................................................................................8-1 8.1 GARD 8000 21L SETTING EXAMPLES – STEPPED DISTANCE ............................................................................................. 8-1 8.2 GARD 8000 21L SETTING EXAMPLES – DIRECTIONAL COMPARISON BLOCKING...................................................... 8-13

SECTION 9. DESCRIPTION OF OPERATION ...................................................................................................9-1 9.1 DISTANCE ELEMENTS................................................................................................................................................................ 9-1 9.2 NON-PILOT AND PILOT SCHEMES......................................................................................................................................... 9-15 9.3 PHASE SELECTOR ..................................................................................................................................................................... 9-28 9.4 FAULT DETECTOR..................................................................................................................................................................... 9-29 9.5 LOSS-OF-POTENTIAL BLOCK.................................................................................................................................................. 9-29 9.6 OPEN POLE LOGIC..................................................................................................................................................................... 9-30 9.7 CLOSE-INTO-FAULT.................................................................................................................................................................. 9-31 9.8 LOAD ENCHROACHMENT ....................................................................................................................................................... 9-33 9.9 POWER SWING BLOCK UNIT .................................................................................................................................................. 9-33 9.10 REMOTE OPEN BREAKER DETECTION............................................................................................................................... 9-35 9.11 OVERCURRENT ELEMENTS .................................................................................................................................................. 9-37 9.12 DIRECTIONAL UNITS.............................................................................................................................................................. 9-55 9.13 DIRECTIONAL OVERCURRENT PILOT SCHEMES............................................................................................................. 9-61 9.14 STUB BUS PROTECTION......................................................................................................................................................... 9-62 9.15 BROKEN CONDUCTOR (PHASE UNBALANCE) UNIT (46)................................................................................................ 9-63 9.16 THERMAL IMAGE UNIT.......................................................................................................................................................... 9-63 9.17 VOLTAGE UNITS...................................................................................................................................................................... 9-65

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9.18 FREQUENCY UNITS (81) ......................................................................................................................................................... 9-68 9.19 BREAKER FAILURE RELAY UNIT ........................................................................................................................................ 9-70 9.20 SYNCH CHECK UNIT............................................................................................................................................................... 9-72 9.21 POLE DISCORDANCE .............................................................................................................................................................. 9-74 9.22 TRIP LOGIC ............................................................................................................................................................................... 9-75 9.23 RECLOSING UNIT .................................................................................................................................................................... 9-76 9.24 BREAKER SUPERVISION FUNCTIONS................................................................................................................................. 9-84 9.25 SERIES COMPENSATED APPLICATIONS............................................................................................................................. 9-85

SECTION 10. SEQUENCE OF EVENTS REPORTS AND FAULT RECORDING...........................................10-1 10.1 MEASURED VALUES, TRIP STATUS, SEQUENCE OF EVENTS AND FAULT RECORDS ............................................. 10-1 10.2 MEASURED VALUES AND TRIP STATUS............................................................................................................................ 10-1 10.3 FAULT LOCATOR................................................................................................................................................................... 10-13

SECTION 11. DISTANCE RELAY LOGIC PROGRAMMING...........................................................................11-1 11.1 OVERVIEW................................................................................................................................................................................ 11-1 11.2 FACTORY DEFAULT PROGRAMMING................................................................................................................................. 11-1 11.3 INPUTS ....................................................................................................................................................................................... 11-1 11.4 OUTPUTS ................................................................................................................................................................................... 11-4 11.5 ZIVERCOM ................................................................................................................................................................................ 11-6 11.6 DISTANCE MODULE COMPLETE SIGNAL LIST............................................................................................................... 11-24

SECTION 12. DISTANCE RELAY COMMISSIONING ......................................................................................12-1 12.1 EQUIPMENT REQUIREMENTS............................................................................................................................................... 12-1 12.2 POWER CONNECTIONS .......................................................................................................................................................... 12-2 12.3 BOOT-UP PROGRESS............................................................................................................................................................... 12-2 12.4 ETHERNET CONNECTION...................................................................................................................................................... 12-3 12.5 LOGIC/SOFTWARE VERIFICATION...................................................................................................................................... 12-3 12.6 DISTANCE RELAY WIRING VERIFICATION....................................................................................................................... 12-4 12.7 DISTANCE RELAY CONFIGURATION SETTINGS VERIFICATION.................................................................................. 12-5 12.8 NOMINAL VOLTAGE AND CURRENT VERIFICATION ..................................................................................................... 12-6 12.9 INPUT/OUTPUT MAPPING VERIFICATION ......................................................................................................................... 12-7 12.10 LED LOGIC ASSIGNMENTS VERIFICATION ..................................................................................................................... 12-9 12.11 SYSTEM CONFIGURATION VERIFICATION ..................................................................................................................... 12-9 12.12 DISTANCE RELAY FUNCTIONAL TESTING.................................................................................................................... 12-10

SECTION 13. INDEX .........................................................................................................................................13-1 SECTION 14. APPLICATION NOTES ...............................................................................................................14-1

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Table of Figures Figure 4-1. Three Phase Operating Times............................................................................................................................. 4-1 Figure 4-2. Two Phase Operating Times ............................................................................................................................... 4-1 Figure 4-3. Single Phase Operating Times ............................................................................................................................ 4-2 Figure 6-1. Front and Rear views of 3U chassis with Distance Relay (Typical) ..................................................................... 6-2 Figure 6-2. External connections for the 3U chassis.............................................................................................................. 6-2 Figure 6-3. Input Mapping web page ..................................................................................................................................... 6-3 Figure 6-4. Output Mapping web page .................................................................................................................................. 6-4 Figure 6-5. Distance relay rear connections .......................................................................................................................... 6-4 Figure 6-6. AC Schematic for GARD 8000 Distance Protection ............................................................................................ 6-5 Figure 6-7. Distance Relay Inputs, schematic diagram.......................................................................................................... 6-6 Figure 6-8. Distance Relay Outputs, schematic diagram....................................................................................................... 6-7 Figure 8-1. Trip Mask Enable and Element Enable (Stepped Distance) ................................................................................ 8-3 Figure 8-2. Trip Mask Enable and Element Enable (Directional Comparison Blocking)....................................................... 8-14 Figure 8-3. Directional Comparison Blocking (DCB) Distance Relay Scheme..................................................................... 8-27 Figure 8-4. Directional Comparison Blocking (DCB) Directional Overcurrent Scheme ........................................................ 8-28 Figure 9-1. MHO Phase-Ground Characteristic (I)................................................................................................................. 9-3 Figure 9-2. Mho Phase-Ground Characteristic (II) ................................................................................................................. 9-4 Figure 9-3. Phase-Phase Mho Characteristic (I).................................................................................................................... 9-5 Figure 9-4. Reactance Characteristic (I) ................................................................................................................................ 9-7 Figure 9-5. Reactance Characteristic (II) ............................................................................................................................... 9-8 Figure 9-6. Directional Unit .................................................................................................................................................... 9-9 Figure 9-7. Resistive Blinder................................................................................................................................................ 9-10 Figure 9-8. AG Distance Element Operational Logic ........................................................................................................... 9-12 Figure 9-9. AB Distance Element Operational Logic............................................................................................................ 9-13 Figure 9-10. Zone Logic....................................................................................................................................................... 9-15 Figure 9-11. Stepped Distance Logic................................................................................................................................... 9-15 Figure 9-12. Zone 1 Extension............................................................................................................................................. 9-16 Figure 9-13. Permissive Underreach Transfer Trip (PUTT) ................................................................................................. 9-17 Figure 9-14. PUTT ............................................................................................................................................................... 9-18 Figure 9-15. Direct Transfer Trip (DTT) ............................................................................................................................... 9-19 Figure 9-16. Permissive Overreach Transfer Trip (POTT) ................................................................................................... 9-19 Figure 9-17. Permissive Overreach ..................................................................................................................................... 9-20 Figure 9-18. Directional Comparison Blocking With Directional Carrier TX ......................................................................... 9-21 Figure 9-19. Directional Comparison Blocking..................................................................................................................... 9-22 Figure 9-20. Directional Comparison Unblocking................................................................................................................. 9-23 Figure 9-21. Directional Comparison Unblocking Diagram .................................................................................................. 9-24 Figure 9-22. Transient Block Logic ...................................................................................................................................... 9-25 Figure 9-23. Transient Block Logic ...................................................................................................................................... 9-25 Figure 9-24. Transient Block Logic Diagram........................................................................................................................ 9-25 Figure 9-25. Weak Infeed Logic........................................................................................................................................... 9-27 Figure 9-26. Phase selector................................................................................................................................................. 9-28 Figure 9-27. Loss-of-Potential Block .................................................................................................................................... 9-29 Figure 9-28. Open Pole Logic with Individual 52b Inputs ..................................................................................................... 9-30 Figure 9-29. Open Pole Logic with One Common 52b Input................................................................................................ 9-31 Figure 9-30. Close-Into-Fault Block Diagram....................................................................................................................... 9-32 Figure 9-31. Load Encroachment Characteristic.................................................................................................................. 9-33 Figure 9-32. Power swing Unit............................................................................................................................................. 9-34 Figure 9-33. Open breaker detector..................................................................................................................................... 9-36 Figure 9-34. Minimum Operating Time for time overcurrent curve....................................................................................... 9-39 Figure 9-35. Minimum Operating Time when set Fixed Time exceeds curve time delay at 1.5 x pick-up............................ 9-39 Figure 9-36. ANSI Moderately Inverse................................................................................................................................. 9-40 Figure 9-37. ANSI Inverse ................................................................................................................................................... 9-41 Figure 9-38. ANSI Very Inverse ........................................................................................................................................... 9-42 Figure 9-39. ANSI Extremely Inverse................................................................................................................................... 9-43 Figure 9-40. ANSI Short time............................................................................................................................................... 9-44 Figure 9-41. Inverse (IEC) ................................................................................................................................................... 9-45 Figure 9-42. IEC Very Inverse ............................................................................................................................................. 9-46 Figure 9-43. IEC Extremely Inverse..................................................................................................................................... 9-47

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Figure 9-44. IEC Long Inverse............................................................................................................................................. 9-48 Figure 9-45. IEC short inverse ............................................................................................................................................. 9-49 Figure 9-46. IEEE Moderately Inverse................................................................................................................................. 9-50 Figure 9-47. IEEE Very Inverse ........................................................................................................................................... 9-51 Figure 9-48. IEEE Extremely Inverse................................................................................................................................... 9-52 Figure 9-49. RI Inverse ........................................................................................................................................................ 9-53 Figure 9-50. Vector diagram for the phase directional unit .................................................................................................. 9-56 Figure 9-51. Application example ........................................................................................................................................ 9-57 Figure 9-52. Ground directional characteristic with voltage polarization .............................................................................. 9-58 Figure 9-53. Zero Sequence Network for a Forward Fault................................................................................................... 9-59 Figure 9-54. Negative Sequence Network for a Forward Fault ............................................................................................ 9-60 Figure 9-55. Directional Overcurrent DCB Scheme ............................................................................................................ 9-62 Figure 9-56. Stub Bus Protection......................................................................................................................................... 9-62 Figure 9-57. Thermal time constant ..................................................................................................................................... 9-64 Figure 9-58. Thermal image characteristic time curves ....................................................................................................... 9-64 Figure 9-59. Block Diagram for Phase Undervoltage units .................................................................................................. 9-66 Figure 9-60. Block Diagram for Phase Overvoltage units .................................................................................................... 9-67 Figure 9-61. Rate of change of frequency............................................................................................................................ 9-69 Figure 9-62. Breaker Failure Relay...................................................................................................................................... 9-71 Figure 9-63. Synchro and Energizing Check Logic.............................................................................................................. 9-74 Figure 9-64. Pole Discordance Logic.................................................................................................................................. 9-74 Figure 9-65. Distance Module Trip Logic ............................................................................................................................. 9-75 Figure 9-66. Reclose Initiate Logic ...................................................................................................................................... 9-77 Figure 9-67. Reclosing Mode............................................................................................................................................... 9-78 Figure 9-68. Recloser lock-out operation ............................................................................................................................. 9-79 Figure 9-69. Recloser lock-out operation ............................................................................................................................. 9-80 Figure 10-1. Distance Measured Values.............................................................................................................................. 10-1 Figure 10-2. Distance Metering............................................................................................................................................ 10-2 Figure 10-3. Distance Protection Unit Status ....................................................................................................................... 10-3 Figure 10-4. Distance Recloser Status ................................................................................................................................ 10-4 Figure 10-5. Distance Status at last trip ............................................................................................................................... 10-5 Figure 10-6. Distance SOE screen ...................................................................................................................................... 10-6 Figure 10-7. Distance SOE detail screen............................................................................................................................. 10-7 Figure 10-8. Distance Fault Record ..................................................................................................................................... 10-8 Figure 10-9. Distance Fault Record Details (Part 1 of 3) ..................................................................................................... 10-9 Figure 12-1. GARD 8000 Controller Module (Commissioning, Distance Relay) .................................................................. 12-2 Figure 12-2. AC Schematic for GARD Distance Protection ................................................................................................. 12-4 Figure 12-3. Distance Relay I/O connections (Commissioning)........................................................................................... 12-5

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List of Tables Table 9-1. MHO Characteristic .............................................................................................................................................. 9-2 Table 9-2. MHO Characteristic Table Definitions................................................................................................................... 9-2 Table 9-3. MHO Phase-Ground Characteristic Definitions..................................................................................................... 9-4 Table 9-4. Phase-Phase Mho Characteristic Definitions........................................................................................................ 9-5 Table 9-5. Quadrilateral Characteristics................................................................................................................................. 9-6 Table 9-6. Quadrilateral Characteristics Definitions............................................................................................................... 9-6 Table 9-7. Directional Unit ..................................................................................................................................................... 9-9 Table 9-8. Directional Unit Definitions.................................................................................................................................... 9-9 Table 9-9. Resistive Limiter Characteristic........................................................................................................................... 9-11 Table 9-10. Resistive Limiter Characteristic Definitions ....................................................................................................... 9-11 Table 9-11. Supervision Elements ....................................................................................................................................... 9-14 Table 9-12. Supervision Elements Definitions ..................................................................................................................... 9-14 Table 9-13. Phase Directional Measurement....................................................................................................................... 9-55 Table 9-14. Phase Directional Element................................................................................................................................ 9-56 Table 9-15. Directional Ground Element.............................................................................................................................. 9-58 Table 9-16. Directional Ground Element (Current Element) ................................................................................................ 9-59 Table 9-17. Directional Negative Sequence Element .......................................................................................................... 9-60 Table 9-18. Angular Compensation ..................................................................................................................................... 9-72 Table 10-1. Oscillographic Record..................................................................................................................................... 10-12 Related Documentation RFL can provide the end user with a GARD 8000 System Emulator on a separate CD; this is not provided with the documentation package. The GARD 8000 System Emulator can be downloaded from the RFL website; www.rflelect.com or alternately ordered from:

RFL Electronics Inc. 353 Powerville Road Boonton, NJ 07005-9151 USA Tel – 973.334.3100 Fax – 973.334.3863 Sales: [email protected] Service: [email protected]

When this CD is installed on your PC it will simulate a complete GARD 8000 System. Installation and operation instructions are included on the CD.

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Customer Resource Center

The RFL Electronics Inc. "On-line Customer Resource Center" has been created to provide customers with "real-time" information necessary to keep RFL equipment operating optimally. The Resource Center contains Application Notes, Service Notices, Product Bulletins, Software Downloads, Software Upgrades, Technical Product Manuals and Sales Brochures, in a convenient and easy-to-use location on our web site. The Resource Center will be updated regularly, so the latest information is always at your fingertips. Registration is free, easy, and ensures your access to the Resource Center at any time. To register please use the link provided on this page.

Once registered at the "Customer Resource Center", RFL will automatically notify you via e-mail when new products are released, or when downloadable documents are available for the categories you have selected. RFL will alert you with important Service Notices that could improve the performance of your product or make you aware of special considerations when applying RFL products in certain applications.

RFL Members Area

April 1, 2010 viii 973.334.3100

http://www.rflelect.com/custsvc/login.asp


WARNING LABELS AND SAFETY SUMMARY Because the Distance Relay Module is always installed in a GARD System Chassis the following safety instructions are included here for added protection.

TO PREVENT ELECTRIC SHOCKPROPER CAUTION MUST BE EXERCISED WHEN SERVICING THIS EQUIPMENT

ALL TERMINALS ON THE REAR OF THIS UNIT MAY HAVE HIGH VOLTAGE

CAUTION

!

3U GARD Unit shown, position oflabels on 6U unit similar

CAUTIONFOR YOUR SAFETY

THE INSTALLATION, OPERATION ANDMAINTENANCE OF THIS EQUIPMENTSHOULD ONLY BE PERFORMED BY

QUALIFIED PERSONS ONLY. !

38-150/200-300 VDC3 AMPS 220 W MAX.

!

RS-499 X.21 V.35

POWER SUPPLY 1 POWER SUPPLY 2

MAJOR MINOR

SW1 SW2

1 0 1 0

Chassis ProtectiveEarth Terminal

The equipment in the GARD System contains high voltage. Exercisedue care during operation and servicing. Read the safety summaryon the following page.!

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SAFETY SUMMARY

The following safety precautions must be observed at all times during operation, service, and repair of this equipment. Failure to comply with these precautions, or with specific warnings elsewhere in this manual, violates safety standards of design, manufacture, and intended use of this product. RFL Electronics Inc. assumes no liability for failure to comply with these requirements.

GROUND THE CHASSIS The chassis must be grounded to reduce shock hazard and allow the equipment to perform properly. Equipment supplied with three-wire ac power cables must be plugged into an approved three-contact electric outlet. All other equipment is provided with a rear-panel protective earth terminal, which must be connected to a proper electrical ground by suitable cabling. Refer to the wiring diagram for the chassis or cabinet for the location of the protective earth terminal. DO NOT OPERATE IN AN EXPLOSIVE ATMOSPHERE OR IN WET OR DAMP AREAS Do not operate the product in the presence of flammable gases or fumes, or in any area that is wet or damp. Operating any electrical equipment under these conditions can result in a definite safety hazard. KEEP AWAY FROM LIVE CIRCUITS Operating personnel should never remove covers. Component replacement and internal adjustments must be done by qualified service personnel. Before attempting any work inside the product, disconnect it from the power source and discharge the circuit by temporarily grounding it. This will remove any dangerous voltages that may still be present after power is removed.

DO NOT SUBSTITUTE PARTS OR MODIFY EQUIPMENT Because of the danger of introducing additional hazards, do not install substitute parts or make unauthorized modifications to the equipment. The product may be returned to RFL for service and repair, to ensure that all safety features are maintained. READ THE MANUAL Operators should read this manual before attempting to use the equipment, to learn how to use it properly and safely. Service personnel must be properly trained and have the proper tools and equipment before attempting to make adjustments or repairs. Service personnel must recognize that whenever work is being done on the product, there is a potential electrical shock hazard and appropriate protection measures must be taken. Electrical shock can result in serious injury, because it can cause unconsciousness, cardiac arrest, and brain damage. Throughout this manual, warnings appear before procedures that are potentially dangerous, and cautions appear before procedures that may result in equipment damage if not performed properly. The instructions contained in these warnings and cautions must be followed exactly.

!

Notice: The use of ungrounded instruments such as hand held voltmeters has been shown to generate Electro-Static Discharge. Care should be taken when using such devices on test points internal to RFL equipment. Specifically, the use of probes manufactured under the Pomona brand is not recommended.

Notice: RFL products are not designed for safety critical direct control of nuclear reactors and should not be used as such.

April 1, 2010 x 973.334.3100

WARNING!

ON INITIAL INSTALLATION, ENSURE THAT ALL MODULES ARE FULLY SEATED INTO CONNECTORS BEFORE POWERING ON UNIT.

CAUTION

THE GARD 8000 CONTAINS STATIC SENSITIVE DEVICES. PERSONS WORKING ON THIS EQUIPMENT MUST OBSERVE ELECTRO STATIC

DISCHARGE (ESD) PRECAUTIONS BEFORE REMOVING THE FRONT COVER OR WORKING ON THE REAR OF THE CHASSIS. AS A MINIMUM YOU MUST DO THE FOLLOWING: USE ANTI-STATIC DEVICES SUCH AS WRIST STRAPS

AND FLOOR MATS, AND LEAVE MODULES IN THEIR ANTI-STATIC BAGS UNTIL THEY ARE READY TO BE INSTALLED.

WARNING!

YOUR GARD 8000 TERMINAL MAY BE EQUIPPED WITH FIBER OPTIC INPUT/OUTPUT MODULES THAT HAVE FIBER OPTIC EMITTER HEADS. FIBER OPTIC EMITTER HEADS USE A LASER LIGHT SOURCE THAT PRODUCE INVISIBLE RADIATION. FIBER OPTIC COMMUNICATION SYSTEMS ARE INHERENTLY SAFE IN NORMAL OPERATION BECAUSE ALL RADIATION IS CONTAINED IN THE SYSTEM. IT IS POSSIBLE DURING MAINTENANCE TO EXPOSE THE RADIATION BY REMOVING OR BREAKING THE FIBER. STARING DIRECTLY INTO THE LIGHT BEAM MAY RESULT IN PERMANENT EYE DAMAGE AND/OR BLINDNESS. NEVER LOOK DIRECTLY INTO THE LIGHT BEAM AND BE CAREFUL NOT TO SHINE THE LIGHT AGAINST ANY REFLECTIVE SURFACE.

THE LASER SOURCE IS A CLASS I LASER PRODUCT WHICH COMPLIES WITH APPLICABLE FDA, OSHA AND ANSI STANDARDS.

GARD 8000 Distance Relay RFL Electronics Inc. April 1, 2010 xi 973.334.3100


LIST OF EFFECTIVE PAGES When revisions are made to the GARD 8000 Distance Relay Instruction Manual, the entire section where revisions were made is replaced. For the edition of this manual dated April 1, 2010 the sections are dated as follows: Front Matter April 1, 2010 Section 1 January, 2009 Section 2 March 1, 2009 Section 3 March 1, 2009 Section 4 March 1, 2009 Section 5 March 1, 2009 Section 6 March 1, 2009 Section 7 July 21, 2009 Section 8 August 1, 2009 Section 9 August 1, 2009 Section 10 March 1, 2009 Section 11 February 9, 2010 – New Release Section 12 March 1, 2009 Section 13 August 1, 2009 Section 14 August 1, 2009 Trademarks: “Ethernet” is a trademark of Xerox Corporation “Windows,” “Windows 98,” “Windows 2000” and “Windows XP” are registered trademarks of Microsoft Corporation.

April 1, 2010 xii 973.334.3100


REVISION RECORD

Rev. Description Date Approval

3-1-09 New Document Release

3-1-09

TG

8-1-09

New Section 8 added (Distance Relay Setting Examples). Remaining sections moved up one section. Section 13 added (Application Notes).

8-1-09

TG

4-1-10

Addition of new section for Logic Programming (Section 11). Remaining sections moved up one.

TG

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Product Information


SECTION 1. PRODUCT INFORMATION Please go to the next page for the following Data Sheet: GARD 8000 Distance Relay Module

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Product Information



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General Description and Overview


SECTION 2. GENERAL DESCRIPTION AND OVERVIEW

2.1 DESCRIPTION The GARD 8000 Distance Module incorporates all functions required for complete line protection. Using the most advanced digital technology, based on microprocessors and DSPs, it provides distance protection, together with current, voltage and frequency protection functions, recloser, synchronism check, supervision functions and metering.

2.2 GENERAL OVERVIEW The GARD 8000 Distance Module provides • Distance measuring elements (with their supervisory units, such as detectors for close onto

fault, remote breaker opening, loss-of-potential, power swing and load encroachment) • Voltage measuring elements (phase over/undervoltage and ground overvoltage) • Current measuring elements (instantaneous and time overcurrent, directional or non directional

phase and ground overcurrent, stub bus and thermal protection, open phase and breaker failure detectors)

• Frequency measuring elements (over/underfrequency and rate of change of frequency) The distance measuring elements may be used in Pilot Protection Schemes to speed up remote-end tripping. In addition, pilot scheme logic for the negative sequence and ground directional elements are also available. These can use the same channel as the distance protection pilot logic, or separate channels. The GARD 8000 Distance Module can be configured for single pole tripping and logic for series compensated line applications is included. The GARD 8000 Distance Module recloser function provides up to 3 reclose attempts. The recloser can be supervised by the built-in synchronism check function, or by the use of an external device. Breaker monitoring functions are provided to detect an excessive number of tripping operations and excessive breaking current. Other GARD 8000 Distance Module features are digital fault records (oscillography), fault reports (with fault location) and event records.

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General Description and Overview



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System Specifications


SECTION 3. SYSTEM SPECIFICATIONS AC Current Inputs Nominal 1 or 5 A Continuous 4 times nominal One second 100 times nominal Burden <0.2 VA for 5 A nominal <0.05 VA for 1 A nominal AC Voltage Inputs Rated voltage 120 Vac @ 60 Hz 110 Vac @ 50 Hz Continuous 2 times nominal Burden <0.05 VA Frequency and Rotation Frequency 50 or 60 Hz Phase rotation ABC or ACB Metering Accuracy Voltages +/- 0.1% (60 - 300V) Currents 5A nominal +/-2 mA/0.1% (0.5-160A) 1A nominal +/-0.5mA/0.1% (0.1-30A) Phase angle +/-0.3 deg Power factor +/-0.001 Frequency +/-0.001 Hz Active/reactive power (5A nominal and >1A load current) 0-180 deg 0.3% +/-15 or 165 deg 0.5% active, 5% reactive +/- 45 or 135 deg 1% active, 1% reactive +/- 75 or 115 deg 5% active, 0.5% reactive +/-90 deg 0.3% reactive

Time measurement Fixed Time: ±1 % of setting or ±20 ms (whichever is greater) Inverse Time: Class 2 (E = 2 %) (UNE 21-136, CEI 255 and ANSI C37.60)

Repeatability Operating Time: < 2% or 25 ms (whichever is greater)

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Distance elements Zones 1 - 4 5A nominal 100 ohms 1A nominal 0.05 - 250 ohms Resistive reach 2 .00 - 10.00 times reactive reach Time delay 0.00 - 300.00 sec Minimum operating time 1 cycle Overcurrent supervision elements 5A nominal 0.20 - 7.50 A 1A nominal 0.04 - 1.5 A Instantaneous/Definite Time Overcurrent Elements 5A nominal 0.10 - 150.00 A 1A nominal 0.02 - 30.00 A Time delay 0.00 - 300.00 seconds Directional Overcurrent Unit Characteristic angle 0 - 90 deg Minimum polarizing voltage 0.00 - 10.00 V Negative or Zero sequence ground directional polarization Time Overcurrent Elements 5A nominal 0.20 - 25.00 A 1A nominal 0.04 - 5.00 A Time Dial ANSI: 0.5 - 10.00 IEC: 0.05 - 1.00 Definite time 0.05 - 300.00 sec ANSI Definite time Moderately inverse Inverse Very inverse Extremely inverse Long time inverse Short time inverse Inverse + maximum time Very inverse + maximum time Extremely inverse + maximum time User defined EN (IEC) curves Definite time Inverse Very inverse Extremely inverse Long time inverse Short time inverse Inverse + maximum time Very inverse + maximum time Extremely inverse + maximum time User defined

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Under- and Overvoltage Elements Pick-up range 20.00 - 300.00 V Time delay 0.00 - 300.00 sec Frequency Elements Pick-up range 40.00 - 70.00 Hz Undervoltage inhibit 20 - 150 V Rate of change 0.5 - 10.00 Hz/s Synchronism Check Elements Voltage difference 2 - 30% Phase angle 5 - 80 deg Slip frequency 0.005 - 2.00 Hz Time delay 0.05 - 300.00 s Recloser No of shots 1 - 3 Dead-time 0.1 - 300 s Reset time 0.05 - 300 s

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Distance Relay Operation Times


SECTION 4. DISTANCE RELAY OPERATING TIMES

Three Phase

0

5

10

15

20

25

10 20 30 40 50 60 70 80 90

% of set reach

mill

isec

onds

SIR=0.1SIR=1SIR=10

Figure 4-1. Three Phase Operating Times

Phase-Phase

0

5

10

15

20

25

30

10 20 30 40 50 60 70 80 90

% of set reach

mill

isec

onds

SIR=0.1SIR=1.0SIR=10

Figure 4-2. Two Phase Operating Times

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Distance Relay Operation Times


Single Phase

0

5

10

15

20

25

10 20 30 40 50 60 70 80 90

% of set reach

mill

isec

onds

SIR=0.1SIR=1SIR=10

Figure 4-3. Single Phase Operating Times

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Standard and Type Tests


SECTION 5. STANDARDS AND TYPE TESTS

The equipment satisfies the standards indicated below. When not specified, the standard is UNE 21-136 (IEC-60255). Insulation Test (Dielectric Strength) IEC -60255-5 Between all circuit terminals and ground: 2 kV, 50/60 Hz, for 1 min; or

2.5 kV, 50/60 Hz, for 1 s Between all circuit terminals: 2 kV, 50/60 Hz, for 1 min; or

2.5 kV, 50/60 Hz, for 1 s Measurement of Insulation Resistance IEC -60255-5

Common mode: R ≥ 100 mΩ or 5µA Differential mode: R ≥ 100 kΩ or 5mA Voltage Impulse Test IEC 60255-5 (UNE 21-136-83/ 5) Common mode (analog inputs, DIs, DOs and OP): 5 kV; 1.2/50 µs; 0.5 J

Differential mode (DOs): 1 kV; 1.2/50 µs Differential mode (Power supply): 3 kV; 1.2/50 µs

1 MHz Burst Test IEC 60255-22-1 Class III (UNE 21-136-92/22-1) Common mode: 2.5 kV Differential mode: 2.5 kV Fast Transient Disturbance Test IEC 60255-22-4 Class IV (UNE 21-136-92/22-4), (IEC 61000-4-4)

4 kV ± 10% Radiated Electromagnetic Field Disturbance IEC 61000-4-3 Class III Amplitude modulated (EN 50140) 10 V/m Pulse modulated (EN 50204) 10 V/m Conducted Electromagnetic Field Disturbance (IEC 61000-4-6) Class III (EN 50141) Amplitude modulated 10 V Electrostatic Discharge IEC 60255-22-2 Class IV (UNE 21-136-92/22-2), (IEC 61000-4-2) On contacts ±8 kV ± 10% In air ±15 kV ± 10% Surge Immunity Test IEC-61000-4-5 (UNE 61000-4-5)

(1.2/50µs – 8/20µs) Between conductors: 4 kV

Between conductors and ground: 4 kV

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Standard and Type Tests


Radiated Electromagnetic Field Disturbance at Industrial Frequency (50/60Hz)

IEC 61000-4-8 Radio Frequency Emissivity EN 55022 (radiated) and EN 55011 (conducted) Temperature IEC 60068-2 Cold work IEC 60068-2-1 -5ºC, 2 hours Cold work limit conditions IEC 60068-2-1 -10ºC, 2 hours Dry heat IEC 60068-2-2 +45ºC, 2 hours Dry heat limit conditions IEC 60068-2-2 +55ºC, 2 hours Humid heat IEC 60068-2-78 +40ºC, 93% relative humidity, 4 days Quick temperature changes IEC 60068-2-14 / IEC 61131-2 IED open, -25ºC for 3 h and +70ºC for 3 h (5 cycles) Changes in humidity IEC 60068-2-30 / IEC 61131-2 +55ºC for 12 h, and +25ºC for 12 h (6 cycles) Endurance test +55ºC during 1000 hours Operating range: From -40ºC to +85ºC Storage range: From -40ºC to +85ºC Humidity: 95% (non-condensing) Climate Test (55º, 99% humidity, 72 hours) Time/current Characteristic ANSI C37.60 Class II Power Supply Interference and Ripple < 20% and 100 ms

IEC 255-11 / UNE 21-136-83 (11) Inverse Polarity of the Power Supply IEC 61131-2 Resistance of Ground Connection IEC 61131-2 < 0.1 Ω Gradual Stop/ Start Test IEC 61131-2 (Test A) Surge Capacity IEC 60044-1 Vibration Test (sinusoidal) IEC 60255-21-1 Class I Mechanical Shock and Bump Test IEC 60255-21-2 Class I External Protection Levels IEC 60529 / IEC 60068-2-75 (IP30 / IK07)

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Configuration


SECTION 6. CONFIGURATION

6.1 SYSTEM CONFIGURATION OVERVIEW The GARD 8000 System differs from most conventional multifunctional distance relays in that rather than supplied with very complex generic default logic, The GARD 8000 is intended to be easily customized to meet your specific application requirements. For most applications, the factory default logic may be suitable but RFL will modify it free-of-charge as required. The advantage with custom logic is that the user interface is greatly simplified as the web pages for logic settings are automatically created to correspond to the actual logic. While the logic is custom made, a considerable amount of settings and field flexibility can be built-in to cover a large number of application needs. For instance, mapping of inputs and outputs, inverters for inputs and outputs, timers, communications channel selections, etc. can all be made on web pages as settings. The distance relay in itself is highly programmable but the interaction in the system has been kept to a minimum in order to simplify the system user interface. Recognizing the need for different functionality for different users and/or applications, the logic signals (in and out) exchanged between the system logic and the distance protection module can be custom specific.

6.2 HARDWARE CONFIGURATION A GARD 8000 System can be built up with Functional Modules as required for a specific application, with a selectable number of inputs, outputs and communications interfaces. Each GARD 8000 is delivered with chassis drawings, showing the actual hardware and the factory default configuration. These drawings are delivered as a paper copy and also in pdf format inside the GARD itself for print-out or viewing on your PC. The following overview describes a factory default configuration of a 3U chassis built up of:

• Single Power Supply • Single Main Controller • Display Board with base Teleprotection System • RS 449 communications port on the rear of the PS module (included in Base System) • C37.94 communications module in rear Slot 1 • Distance Protection module in front and rear Slot 3 • 12 input module in rear Slot 2 • 12 output module (6 solid state and 6 relay out) in rear Slot 4

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Configuration


+

-

+

-

PS

48/

125V

Chassis Front View

Chassis Rear View Single Power Supply

Single Main Controller (Slot 2)

Display with TPS (Slot 1) Distance Relay (Slot 3)

RS-449C37.94 Comms Module (Slot 1)

Distance Relay (Slot 3)

Input Module (Slot 2)

Output Module (Slot 4)

Single Power Supply

Figure 6-1. Front and Rear views of 3U chassis with Distance Relay (Typical) External DC connections are made as shown in the following the schematic for the example system configuration.

IN 1

IN 2

IN 3

IN 4

IN 5

IN 6

IN 7

IN 8

OUT 1

OUT 2

OUT 3

OUT 4

OUT 5

OUT 6

OUT 7

OUT 8

Rear Slot 4

Rear Slot 2

Rear Slot 1

13

1415161718192021222324

13

1514

16

1

2

3

4

65

78

910

11

12

1413

15

16 Figure 6-2. External connections for the 3U chassis

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Configuration


The inputs (Slot 2) and outputs (Slot 4) are user configurable and is setup using a web page:

Figure 6-3. Input Mapping web page

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Configuration


The number of physical inputs depends on how many input modules were ordered. The logic inputs (shown on the left on the input mapping page) are determined in the Orcad logic, and can be customized for your application. The above example shows logic with a distance relay and an 8 function teleprotection system. Outputs are configured in a similar way. Again, the number of physical outputs depends on how many output modules that were ordered. The logic outputs (shown on the left on the output mapping page as ‘source’) are determined in the Orcad logic, and can be customized for your application. The example below shows logic with a distance relay and an 8 function teleprotection system.

Figure 6-4. Output Mapping web page

The rear terminals on Slot 3 are assigned as follows:

12346 58910 714 13 12 1118 17 16 1521 20 19222324

ChassisGND

VA+VC+VC- VA-VB+VB-Chassis

GND

IA+IA-IB+Chassis

GND

IB-IC+Chassis

GND

IC-Chassis

GNDChassis

GND

Rear Slot 3

IPol+VSyn-

VSyn+

IPol-IPN- IPN+

Figure 6-5. Distance relay rear connections

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Configuration


The terminals for the distance relay are fixed, and should be wired according to the AC schematic:

2

3

4

5

6

7

8

9

GARD 8000

A

B

C

Slot 3

VA

VB

VC

VA

VB

VC

VN

V synccheck

13

14

16

17

19

20

IA

IB

IC

I sensitive neutralor currentpolarizing

I neutral fromparallel line forfault locator

10

11

22

23

IA

IB

IC

52

IN

Figure 6-6. AC Schematic for GARD 8000 Distance Protection

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Configuration


To fully understand what the inputs and outputs are doing in the system logic, the actual System Logic Diagram should be consulted. This is supplied at the rear of the GARD 8000 manual and is also available for download or viewing from the GARD file operations menu. For example, the distance relay inputs are shown as follows

Input Mapping

VT_fuse_fail

Ext_Reclose_Init

IN_52B_A

Manual_Close

EXT_OSC_IN

EXT_SYNC_CHECK

VTFUSEFAIL

EXTRECLOSEINIT

52_PHASE_A

MANUALCLOSE

EXTOSCIN

EXTSYNCCHECK

Distance Relay in Slot S3Logic Start Bit 272

A_TRIP

B_TRIP

C_TRIP

3_PH_TRIP

TB2-13TB2-14TB2-15TB2-16TB2-17TB2-18TB2-19TB2-20TB2-21TB2-22TB2-23TB2-24

Input 1

Input 2

Input 3

Input 4

Input 5

Input 6

6 InputSlot 2 Left

MODULE3

Input 1

Input 2

Input 3

Input 4

Input 5

Input 6

12

3

12

3

12

3

IN_52B_B

IN_52B_C

U8

U9

U11

52_PHASE_B

52_PHASE_C

23 1

4

PILOT_TRIP

A_RETRIP

B_RETRIP

C_RETRIP

3_PH_RETRIP

BFR_PICKUP

BFR_TRIP

AG

BG

CG

AB

BC

CA

ABG

BCG

CAG

3_PHASE

XOR2

XOR2

XOR2

OR3

HMIIN1

HMIIN1

HMIIN2

HMIIN2

HMIIN24

HMIIN24

U12

Figure 6-7. Distance Relay Inputs, schematic diagram

The logic inside the ‘distance’ block on the schematic is fixed as delivered from the factory but can be custom ordered for your application. While the proven logic in the distance relay is not changed, the input and output signals of the distance block can be customized to provide different functionality for different applications. A complete list of available signals is provided at the end of this section. The physical inputs (in this example Inputs 1 – 12) are mapped on the webpage to logic inputs. Any physical input can be freely assigned to any number of logical inputs. For example, the default distance relay configuration uses 52b inputs per phase. One external combined 52b input can be mapped to all three logical inputs. On the other hand, if a breaker with single pole operating mechanism is used, the three physical inputs can be wired individually to GARD 8000 inputs to provide pole discrepancy protection.

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Configuration


The outputs are mapped in a similar way. Output Mapping

Output 1

6 Relay OutletsSlot 4 Left

TB2-13TB2-14TB2-15TB2-16TB2-17TB2-18TB2-19TB2-20TB2-21TB2-22TB2-23TB2-24

Output 2

Output 3

Output 4

Output 5

Output 6

Output 1

Output 2

Output 3

Output 4

Output 5

Output 6

TRIP_Distance_1

TRIP_Distance_2

RETRIP_BKR_FAIL_1

U325

RETRIP_BKR_FAIL_2

BFR_pickup

12BUF

12BUF

U326

IN OUT2 1

TIMERNUMBER = 32ATT_DEC = 1_5

U3

12BUF

BFR_trip_out_1

BFR_trip_out_2

12BUF

U10

HMI1OUT1

HMI1OUT2

HMI1OUT3

HMI1OUT4

U327

23 1

4OR3

U13

HMI1OUT5

2

3

1OR2

U17HMI1OUT6

HMI1OUT7

TRIP DISTANCE

BFR TRIP

BFR RE-TRIP

DISTANCE PILOT

SINGLE PHASE FAULT

HMI1OUT8

HMI1OUT9

TWO PHASE FAULT

GROUND

THREE PHASE FAULT

PHASE A

LED MAPPING SIGNALS

Figure 6-8. Distance Relay Outputs, schematic diagram

The logical outputs available are defined in the Orcad logic and can be customized for your application. A logic output can be mapped to a single physical output only, and that is why some logic signals are duplicated in the logic. In case there is a need for more alarm or trip contacts, this can be simply provided by a custom made logic for your needs. The GARD 8000 System provides 20 user configurable LED’s. Each LED is tri-colored; red, yellow, and green. Each color can individually represent a logic function. In case more than one color is active, red will override yellow and green and yellow will override green. The distance relay logic also includes a block named ‘LED MAPPING SIGNALS’. These signals are created for simple mapping to the front panel LED’s. Again, custom made logic can provide other and/or more signals as required. Each LED function can be given a label. The front panel label can also be custom made by a print-out of the supplied template. While there is limited space for text on the front, the web page user labels can contain up to 32 characters.

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Configuration


6.3 LOGIC SIGNALS AVAILABLE FROM THE DISTANCE PROTECTION MODULE

The distance relay module creates a number of logic signals from its measuring element and protection logic. The GARD 8000 System logic uses these signals to perform trip and pilot scheme operations. The default logic is bringing out some of the available signals, but all of the signals shown in the logic diagrams in the GARD System Instruction Manual are available for custom logic.

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Distance Relay Settings

GARD 8000 Distance Relay RFL Electronics Inc. July 21, 2009 7-1 973.334.3100

SECTION 7. DISTANCE RELAY SETTINGS

7.1 GENERAL SETTINGS Description Range Units Step Default Enable distance protection Sets all distance protection module functions ON or OFF No - Yes - 1 On RX Logic Bus Start Bit Used by system logic. Factory set. 3-511 - 1 300 RX Logic Bus Length Used by system logic. Factory set. 0-64 - 1 64 TX Logic Bus Start Bit Used by system logic. Factory set. 3-511 - 1 364 TX Logic Bus Length Used by system logic. Factory set. 0-64 - 1 64 Active Setting Group Determines setting group in use by the distance protection module

Group 1 Group 2 Group 3 Group 4 - 1 Group 4

Line CT ratio Current transformer ratio for the protected line. For example, a 2000/5 A CT has the ratio 400. 1 - 3000 - 1 1 Line PT Ratio Voltage transformer ratio for the protected line. For example, a 115,000/120 V PT has the ratio 1125. 1 - 10000 - 1 1 Bus PT Ratio Voltage transformer ratio for a bus voltage used for the synchro-check function. For example, a 115,000/120 V PT has the ratio 1125. 1 - 10000 - 1 1 Polarization CT ratio Current transformer ratio for a CT used for current ground polarization. 1 - 3000 - 1 1 Parallel line CT Ratio Current transformer ratio for the CT on a parallel line used for mutual coupling compensation for the fault locator. 1 - 3000 - 1 1 Excessive Trips Maximum number of breaker trips during a half hour interval. Performed by the breaker monitoring function. 1 - 40 - 1 40 I² Sum Alarm Alarm level for accumulated breaking current. 0 - 99999.99 kA² 0.01 0 I² Dropout Value The dropout value is used to reset the counter following breaker maintenance (then set to 0). It can also be set to a value corresponding to estimated breaking current at the time GARD 8000 is put into service, enabling a ‘start’ value for the counter other than 0. 0 - 99999.99 kA² 0.01 0 Capacitive VT Enable (Yes) or disable (No) the use of CCVT filter for the distance relay. No - Yes - 1 No



7.2 LINE PROTECTION SYSTEM SETTINGS

Description Range Units Step Default Line positive sequence magnitude Positive sequence impedance magnitude for the protected line in secondary ohms 0.01 - 100 Ohm 0.01 1.25 Line positive sequence angle Positive sequence impedance angle for the protected line in degrees 5 - 90 deg 1 75 Positive sequence angle Zone 2 Positive sequence impedance angle for the protected line sections for Zone 2 in degrees 5 - 90 deg 1 75 Positive sequence angle Zone 3 Positive sequence impedance angle for the protected line sections for Zone 3 in degrees 5 - 90 deg 1 75 Positive sequence angle Zone 4 Positive sequence impedance angle for the protected line sections for Zone 4 in degrees 5 - 90 deg 1 75 Zone 1 k0 Factor Zero sequence compensation factor magnitude for Zone 1. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 4 Line zero sequence angle Zero sequence impedance angle for the protected line in degrees 5 - 90 deg 1 75 Zone 2 k0 Factor Zero sequence compensation factor magnitude for Zone 2. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 4 Zone 2 zero sequence angle Zero sequence impedance (ZO) angle in degrees for Zone 2. 5 - 90 deg 1 75 Zone 3 k0 Factor Zero sequence compensation factor magnitude for Zone 3. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 4 Zone 3 zero sequence angle Zero sequence impedance (ZO) angle in degrees for Zone 3. 5 - 90 deg 1 75 Zone 4 k0 Factor Zero sequence compensation factor magnitude for Zone 4. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 4 Zone 4 zero sequence angle Zero sequence impedance (ZO) angle in degrees for Zone 4. 5 - 90 deg 1 75 Local source positive sequence magnitude Positive sequence impedance magnitude for the local source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 1.25 Local source positive sequence angle Positive sequence impedance angle for the local source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 75 Local source zero sequence magnitude Zero sequence impedance magnitude for the local source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 1.25

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Description Range Units Step Default Local source zero sequence angle Zero sequence impedance angle for the local source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 75 Remote source positive sequence magnitude Positive sequence impedance magnitude for the remote source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 1.25 Remote source positive sequence angle Positive sequence impedance angle for the remote source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 75 Remote source zero sequence magnitude Zero sequence impedance magnitude for the remote source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 1.25 Remote source zero sequence angle Zero sequence impedance angle for the remote source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 75 Parallel line positive sequence magnitude Positive sequence impedance magnitude for a parallel line in secondary ohms. Used for mutual compensation for the fault locator.

0.01 - 10000 Ohm 0.01 1.25

Parallel line positive sequence angle Positive sequence impedance angle for a parallel line in degrees. Used for mutual compensation for the fault locator. 5 - 90 deg 1 75 Parallel line zero sequence magnitude Zero sequence impedance magnitude for a parallel line in secondary ohms. Used for mutual compensation for the fault locator.

0.01 - 10000 Ohm 0.01 1.25

Parallel line zero sequence angle Zero sequence impedance angle for a parallel line in degrees. Used for mutual compensation for the fault locator. 5 - 90 deg 1 75 Fault locator units Determines display of fault locator calculation in % (% of Length) or in kilometers/miles (Length Units) as set for the parameter ‘Length Units’.

Length Units % of Length - 1

% of Length

Line length Total line length in kilometers or miles, as set for the parameter ‘Length Units’. 0 - 400 - 0.01 100 Indication zone Determines if fault location should be calculated and displayed for faults on the protected line only (In) or for all faults that are detected by the distance relay (In & Out)

In In & Out - 1 In & Out

Length units Determines display of fault locator calculation in kilometers or miles, when parameter ‘Fault Locator Units’ is set to ‘Length Units’.

KilometersMiles - 1 Miles

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Description Range Units Step Default Mutual coupling factor Mutual coupling factor to a parallel line for mutual compensation of the fault locator. The coupling factor is determined as |Z0/Zm0| 0 - 10 Ohm 0.01 0 Mutual coupling angle Mutual coupling angle to a parallel line for mutual compensation of the fault locator. The angle is determined as LZ0 - LZm0 5 - 90 deg 1 25 Mutual coupling enable Turns mutual coupling compensation ON or OFF. For mutual coupling, the neutral ct current from the parallel line needs to be wired into the GARD 8000 relay. No - Yes - 1 No Pickup report This setting determines whether fault records should be triggered from pick-up of any element (YES) or following a trip only (NO). No - Yes - 1 Yes Three pole trip Selects 3-pole tripping (Yes) or single pole tripping (No) No – Yes - 1 Yes Single pole trip from 67G Selects 3-pole tripping (No) or single pole tripping (Yes) from the directional ground element No – Yes - 1 No Z1 ground units Enables trip operation by Zone 1 ground distance units

Disable - Enable - 1 Enable

Z1 phase units Enables trip operation by Zone 1 phase distance units


Z2 ground units Enables trip operation by Zone 2 ground distance units












Remote open breaker logic Enables the remote open breaker logic.

Disable - Enable - 1 Disable

Close Into Fault Enables the close into fault logic.


Stub bus protection Enables the stub bus protection logic.


Thermal Image Enables the thermal image element.


Open phase detector (46) Enables open phase/broken conductor detector logic.


Pole discrepancy Enables the pole discrepancy logic.


Power swing trip Enables out of step trip operation.


50P-1 Enables trip by Instantaneous Phase Overcurrent, step 1.




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Description Range Units Step Default 50P-3 Enables trip by Instantaneous Phase Overcurrent, step 3.


51P-1 Enables trip by Phase Timeovercurrent, step 1.






50G-1 Enables trip by Instantaneous Ground Overcurrent, step 1.






51G-1 Enables trip by Ground Timeovercurrent, step 1.






50Q-1 Enables trip by Instantaneous Negative Sequence Overcurrent, step 1.






51Q-1 Enables trip by Negative Sequence Timeovercurrent, step 1.






59-1 Enables trip by Phase Overvoltage, step 1.






27-1 Enables trip by Phase Undervoltage, step 1.






59G-1 Enables trip by Ground Overvoltage, step 1.




81-1 Underfrequency Enables trip by Underfrequency, step 1.


81-2 Underfrequency Enables trip by Underfrequency, step 2.


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Description Range Units Step Default 81-3 Underfrequency Enables trip by Underfrequency, step 3.


81-1 Overfrequency Enables trip by Overfrequency, step 1.






81-1 Rate-of-change of frequency Enables trip by Rate-of-change of Frequency, step 1.






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7.3 DISTANCE ELEMENTS

7.3.1 ZONE 1 TO ZONE 4 Description Range Units Step Default Zone 1 enable Enable operation of Zone 1 distance No – Yes 1 1 Yes Zone 1 direction Zone 1 measuring direction, forward or reverse.

Reverse Forward - 1 Forward

Zone 1 reach Zone 1 reactive reach in secondary ohms, at set characteristic line angle. 0.01 - 100 Ohm 0.01 0.8 Zone 1 ground resistive reach Resistive reach in secondary ohms for Zone 1 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 – 100 - 0.01 4 Zone 1 phase resistive reach Resistive reach in secondary ohms for Zone 1 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 1 ground timer Zone 1 ground elements time delay 0 - 300 s 0.01 0 Zone 1 phase timer Zone 1 phase elements time delay 0 - 300 s 0.01 0 Zone 1 quad tilt time delay Time delay for the load compensation of the reactive quadrilateral line. After this time, the load compensation is turned off and the line reverts to being parallel with the R-axis. Recommended time delay is 0.08 s (80 ms). 0 - 0.5 s 0.01 0 Zone 2 enable Enable operation of Zone 2 distance No – Yes - 1 Yes Zone 2 direction Zone 2 measuring direction, forward or reverse.


Zone 2 reach Zone 2 reactive reach in secondary ohms, at set characteristic line angle. 0.01 - 100 Ohm 0.01 1.2 Zone 2 ground resistive reach Resistive reach in secondary ohms for Zone 2 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 - 100 - 0.01 4 Zone 2 phase resistive reach Resistive reach in secondary ohms for Zone 2 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 2 ground timer Zone 2 ground elements time delay 0 - 300 s 0.01 0.25s Zone 2 phase timer Zone 2 phase elements time delay 0 - 300 s 0.01 0.25s Zone 3 enable Enable operation of Zone 3 distance No – Yes - 1 Yes Zone 3 direction Zone 3 measuring direction, forward or reverse.


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Description Range Units Step Default Zone 3 reach Zone 3 reactive reach in secondary ohms, at set characteristic line angle. 0.01 – 100 Ohm 0.01 3 Zone 3 ground resistive reach Resistive reach in secondary ohms for Zone 3 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 – 100 - 0.01 4 Zone 3 phase resistive reach Resistive reach in secondary ohms for Zone 3 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 3 ground timer Zone 3 ground elements time delay 0 - 300 s 0.01 0.5s Zone 3 phase timer Zone 3 phase elements time delay 0 - 300 s 0.01 0.5s Zone 4 enable Enable operation of Zone 4 distance No – Yes - 1 Yes Zone 4 direction Zone 4 measuring direction, forward or reverse. Note that when the pilot logic “Directional Comparison Blocking’, “Weak Infeed” and/or ‘Transient Block” is used, Zone 4 is always reverse, regardless of this setting.

Reverse Forward - 1 Reverse

Zone 4 reach Zone 4 reactive reach in secondary ohms, at set characteristic line angle. 0.01 - 100 Ohm 0.01 2.5 Zone 4 ground resistive reach Resistive reach in secondary ohms for Zone 4 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 - 100 - 0.01 4 Zone 4 phase resistive reach Resistive reach in secondary ohms for Zone 3 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 4 ground timer Zone 4 ground elements time delay 0 - 300 s 0.01 0.75s Zone 4 phase timer Zone 4 phase elements time delay 0 - 300 s 0.01 0.75s Ground characteristic Selection of mho, reactance (quadrilateral), mho AND reactance, mho OR reactance for the ground distance elements. Note that the setting ‘Mho AND reactance’ requires both characteristics to operate for a trip to be produced. ‘Mho OR reactance’ produces a trip from either element. For applications when a larger resistive reach as compared to the reactive reach is required, the setting ‘Reactance’ or ‘Reactance OR Mho’ should be used.

Reactance, Mho, Reactance and MHO, Reactance OR MHO - 1 Mho

Phase characteristic Selection of mho, reactance (quadrilateral), reactance AND mho, reactance OR mho the phase distance elements.

Reactance, Mho, Reactance and MHO, Reactance or MHO - 1 Mho

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Description Range Units Step Default Directional line characteristic angle (quad) Characteristic line angle in degrees for the directional element for the quadrilateral characteristic. It is typically set at 75 degrees. See Description of Operation for definition of this angle. 0 - 90 deg 1 75 Lagging phase for two-phase-to-ground faults For two-phase-to-ground faults, the leading phase-ground element may overreach and is not allowed to measure. The lagging phase can be allowed to operate as it will underreach and is enabled by this setting. Two phase to ground faults will generally by detected by phase-phase elements, but in case high resistance is expected for these type of faults, the setting should be YES. No - Yes - 1 No Polarization memory duration This setting determines the polarization voltage memory duration, in cycles. Recommended setting is 2 cycles. 2 - 80 Cycles 1 6 Positive sequence voltage threshold Voltage threshold for the memory polarization. When the measured voltage is below the set threshold, memory is used. 0.1 – 5 V 0.1 1

7.3.2 PILOT (COMMS SCHEME) Description Range Units Step Default Open breaker carrier send Enables open breaker carrier send. Used with Permissive schemes (PUTT, POTT, DCUB, DTT). No - Yes - 1 Yes Security time Sets a pickup delay for a carrier receive signal. This will ensure that no spurious carrier signal will cause a false trip at the receiving end. 0 - 50 ms 1 0 Weak infeed undervoltage level Sets the undervoltage threshold for Weak Infeed tripping. 15 - 70 V 0.01 45 LOP Block weak infeed Enables block of weak infeed tripping by loss-of-potential block. No - Yes - 1 No Distance pilot scheme Selects the type of scheme used.

Step Distance Zone 1 Extension PUTT DTT POTT DCUB DCB - 1

Step Distance

Distance carrier send extend time Sets the drop-out delay for carrier send. 0 - 200 ms 10 50 Distance extend time Sets a coordination drop-out time delay for the carrier start signal from the reverse blocking zone, providing transient block function. 0 - 50 ms 1 25 DCB distance coordination time Sets the time delay for Directional Comparison Blocking (DCB) trip signal. This is the amount of time the forward pilot zone will wait to receive a blocking carrier signal before trip is released. 0 - 200 ms 10 50

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Description Range Units Step Default Z1 extension block time This is the time following breaker closing for when Zone 1 extension will become active. This prevents trip from an overreaching zone following reclosing. Used for Zone 1 Extension scheme. 0.05 - 300 s 0.01 10 Overreaching Zone Determines which zone is used as overreaching Pilot zone (Z2 or Z3).

Zone 2 Zone 3 - 1 Zone 2

Distance weak infeed logic output Set whether to use weak infeed echo (echo), week infeed trip and echo (ECHO+TRIP) or no weak infeed logic (None)

None Echo ECHO+TRIP - 1 None

Distance transient block enable Enable Transient Block Logic for the overreaching permissive pilot schemes (POTT, DCUB) No - Yes - 1 No Carrier fast start This setting is applicable to Directional Comparison Blocking (DCB) only and enables to select Carrier Start from non-directional phase and ground overcurrent elements, in addition to the reverse blocking zone. The 50P-1, 50G-1 elements are utilized for this function. No - Yes - 1 No 67 Pilot Scheme Selects the type of pilot scheme to use for the directional overcurrent elements.

None PUTT DTT POTT DCUB DCB - 1 DCB

67 Carrier send extend time Sets the time delay for carrier send. Used with Permissive schemes (PUTT, POTT, DCUB, DTT). 0 - 200 ms 10 50 67 extend time Sets the coordination drop-out time delay for the carrier start signal. Used with Blocking schemes (DCB). 0 - 50 ms 1 25 67 DCB coordination time Sets the time delay for Directional Comparison Blocking (DCB) trip signal. This is the amount of time the forward overcurrent element zone will wait to receive a blocking carrier signal before trip is released. 0 - 200 ms 10 50 67 Weak infeed logic output Set whether to use weak infeed echo (echo), week infeed trip and echo (ECHO+TRIP) or no weak infeed logic (None) for the overcurrent directional comparison pilot schemes.


67 transient block enable Enable Transient Block Logic for the overcurrent directional comparison pilot schemes. No - Yes - 1 No

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7.3.3 POWER SWING BLOCK AND OTHER ADVANCED FUNCTIONS Description Range Units Step Default Power swing block enable Enables Power swing Blocking No - Yes - 1 No Power swing trip enable Enables Power swing Tripping No - Yes - 1 No Blinders angle Characteristic angle for the power swing blinders 0 - 90 deg 1 75 Forward outer reach Forward reach of the outer upper blinder 0.1 - 100 Ohm 0.01 10 Forward middle reach Forward reach of the middle upper blinder 0.1 - 100 Ohm 0.01 5 Forward inner reach Forward reach of the inner upper blinder. The inner blinder is used for power swing tripping only. 0.1 - 100 Ohm 0.01 1 Reverse outer reach Reverse reach of the outer lower blinder 0.1 - 100 Ohm 0.01 10 Reverse middle reach Reverse reach of the middle lower blinder 0.1 - 100 Ohm 0.01 5 Reverse inner reach Reverse reach of the inner lower blinder. The inner blinder is used for power swing tripping only. 0.1 - 100 Ohm 0.01 1 Right outer resistance Resistance reach of the outer right blinder 0.1 - 500 Ohm 0.01 10 Right middle resistance Resistance reach of the middle right blinder 0.1 - 500 Ohm 0.01 5 Right inner resistance Resistance reach of the inner right blinder. The inner blinder is used for power swing tripping only. 0.1 - 500 Ohm 0.01 1 Left outer resistance Resistance reach of the outer left blinder 0.1 - 500 Ohm 0.01 10 Left middle resistance Resistance reach of the middle left blinder 0.1 - 500 Ohm 0.01 5 Left inner resistance Resistance reach of the inner left blinder. The inner blinder is used for power swing tripping only. 0.1 - 500 Ohm 0.01 1 I1 supervision The minimum required positive sequence current for release of power swing measuring elements. 0.2 - 50 A 0.01 1 Power swing detection time The swing detection time between the outer (external) and middle (medium) blinders. 0 - 1 s 0.002 0.03 Power swing reset time Reset time of the power swing condition. If the impedance locus remains in the distance zone operating characteristic longer than this time, power swing blocking is inhibited and the relay will trip. 0.1 - 5 s 0.1 1 Power swing trip type Power swing tripping can be selected on the Way-In (Fast trip) or Way-Out (Slow trip).

Fast trip Slow trip - 1 Slow trip

Time delay Way-In Time delay for the Way-In trip operation. 0 - 1 s 0.002 0.05 Power swing condition reset time Reset time for the power swing condition following a swing locus moving outside the outer (external) blinder. 0.02 - 1 s 0.002 0.05

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Description Range Units Step Default Distance pilot scheme power swing block Enable block of pilot distance scheme by power swing block.


Z1 Power swing block Enable block of Zone 1 distance scheme by power swing block.


Z2 Power swing block Enable block of Zone 2 distance elements by power swing block.






Arc detector enable Enables arc detection function No - Yes - 1 No Arc detector pickup Arc current detector threshold 0.05 - 1 s 0.01 0.05 Arc detector time Arc current detector trip delay 0.1 - 2 s 0.01 0.1 LOP (fuse fail) enable Enable fuse failure (loss-of-potential) function No - Yes - 1 No LOP reset time Drop out delay for loss-of-potential detection signal 0 - 1000 ms 50 150 LOP block enable Enable blocking of distance protection zone elements by the loss-of-potential function No - Yes - 1 No Load encroachment enable Enable the load encroachment logic No - Yes - 1 No Right area limit Load encroachment forward load area resistive reach setting 0.1 - 100 Ohm 0.01 65 Left area limit Load encroachment reverse load area resistive reach setting 0.1 - 100 Ohm 0.01 65 Right area angle Load encroachment forward load area angle setting 0 - 90 deg 1 20 Left area angle Load encroachment reverse load area angle setting 0 - 90 deg 1 20 Open pole selection Open pole can be selected to used three 52b (or 52a) inputs (setting ‘3 inputs’) or using one input that can either be an OR of the 52b contacts or an AND from the 52b contacts. The factory default logic is supplying individual 52b signals to the distance relay and this setting should be ‘3 inputs’

3 inputs, 2 inputs - 1 3 inputs

A open pole current level Phase A current needs to be below this setting for an open pole to be declared 0.200 – 4 A 0.01 0.2 B open pole current level Phase B current needs to be below this setting for an open pole to be declared 0.200 – 4 A 0.01 0.2 C open pole current level Phase C current needs to be below this setting for an open pole to be declared 0.200 – 4 A 0.01 0.2 Stub bus enable Enable stub bus protection. No - Yes - 1 No Stub but pickup Pickup current threshold for stub bus trip. 0.10 - 150 A 0.01 10 Stub bus time delay Trip time delay for stub bus trip. 0 - 100 s 0.01 0

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Description Range Units Step Default Series compensation enable Enables series compensation logic No – Yes - 1 No Series compensation time delay Drop-out delay of the series compensation transient block signal 0 – 100 s 0.01 1 Series compensation Zone 4 supervision Determines if Zone 4 reverse element is used for the transient block logic No – Yes - 1 No Series compensation 67-G3 supervision Determines if ground overcurrent reverse element (67G/50G-3) is used for the transient block logic No – Yes - 1 No Series compensation 67Q-3 supervision Determines if negative sequence reverse element (67Q/50Q-3) is used for the transient block logic No – Yes - 1 No Series compensation 67P-3 supervision Determines if phase overcurrent reverse element (67/50P-3) is used for the transient block logic No – Yes - 1 No Close Into Fault (CIFT) enable No - Yes - 1 No CIFT supervision zone Selects the distance zone used for close-into-fault (Z2 or Z3).


CIFT overcurrent pickup Overcurrent threshold for Close-Into-Fault operation. 1 - 30 A 0.05 10 Z1 extension after reclosing Selects if the ‘CIFT Sup. Zone’ is allowed to trip following reclosing. No - Yes - 1 No 2nd harmonic restraint Set the % for 2nd harmonic restraint following breaker closing. 0 - 50 % 1 0 Pole discordance enable Enables pole discrepancy logic. No - Yes - 1 No Pole discordance delay Time delay for pole discrepancy trip. 0 - 50 s 0.01 2 81 Inhibit Voltage Inhibit voltage for frequency measurements. When the voltage is below the set threshold, all frequency elements are disabled. 2 - 150 V 1 40 81 Pickup Time Activation time (Pickup time) set in number of half cycles. This setting determines the number of half cycles used for measuring the frequency before a frequency condition can be declared. 3 - 30 scycs 1 6 81 Dropout Time De-activation time (drop-out time) set in number of cycles. This determines the number of cycles used to determine that the frequency has returned to a non-faulted condition. When the frequency units have picked up but not yet tripped, there could be a change in frequency of a short duration and this setting prevents the units from dropping out for such a condition. 0 - 10 cycls 1 0 81M-1 Overfrequency enable Enables overfrequency, step 1 No - Yes - 1 No 81M-1 Overfrequency pickup Pickup threshold for overfrequency, step 1 40 - 70 Hz 0.01 70 81M-1 Overfrequency time delay Pickup time delay for overfrequency, step 1 0 - 300 s 0.01 0 81M-1 Dropout Time Drop-out time delay for overfrequency, step 1 0 - 300 s 0.01 2 81M-2 Overfrequency enable Enables overfrequency, step 2 No - Yes - 1 No

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Description Range Units Step Default 81M-2 Overfrequency pickup Pickup threshold for overfrequency, step 2 40 - 70 Hz 0.01 70 81M-2 Overfrequency time delay Pickup time delay for overfrequency, step 2 0 - 300 s 0.01 0 81M-2 Dropout Time Drop-out time delay for overfrequency, step 2 0 - 300 s 0.01 2 81M-3 Overfrequency enable Enables overfrequency, step 3 No - Yes - 1 No 81M-3 Overfrequency pickup Pickup threshold for overfrequency, step 3 40 - 70 Hz 0.01 70 81M-3 Overfrequency time delay Pickup time delay for overfrequency, step 3 0 - 300 s 0.01 0 81M-3 Dropout Time Drop-out time delay for overfrequency, step 3 0 - 300 s 0.01 2 81m-1 Underfrequency enable Enables underfrequency, step 1 No - Yes - 1 No 81m-1 Underfrequency pickup Pickup threshold for underfrequency, step 1 40 - 70 Hz 0.01 40 81m-1 Underfrequency time delay Pickup time delay for underfrequency, step 1 0 - 300 s 0.01 0 81m-1 Dropout Time Drop-out time delay for underfrequency, step 1 0 - 300 s 0.01 2 81m-2 Underfrequency enable Enables underfrequency, step 2 No - Yes - 1 No 81m-2 Underfrequency pickup Pickup threshold for underfrequency, step 2 40 - 70 Hz 0.01 40 81m-2 Underfrequency time delay Pickup time delay for underfrequency, step 2 0 - 300 s 0.01 0 81m-2 Dropout Time Drop-out time delay for underfrequency, step 2 0 - 300 s 0.01 2 81m-3 Underfrequency enable Enables underfrequency, step 3 No - Yes - 1 No 81m-3 Underfrequency pickup Pickup threshold for underfrequency, step 3 40 - 70 Hz 0.01 40 81m-3 Underfrequency time delay Pickup time delay for underfrequency, step 3 0 - 300 s 0.01 0 81m-3 Dropout Time Drop-out time delay for underfrequency, step 3 0 - 300 s 0.01 2 81D-1 Frequency rate-of-change (ROC) enable Enables rate-of-change of frequency, step 1 No - Yes - 1 No 81D-1 ROC underfrequency pickup Pickup threshold for underfrequency for the rate-of-change of frequency element, step 1 40 - 70 Hz 0.01 40 81D-1 ROC frequency pickup Pickup threshold for rate-of-change of frequency, step 1 -10 - -0.5 Hz/s 0.01 -1 81D-1 ROC frequency time delay Pickup time delay for rate-of-change of frequency, step 1 0 - 300 s 0.01 0 81D-1 Dropout Time Drop-out time delay for rate-of-change of frequency, step 1 0 - 300 s 0.01 2 81D-2 Frequency rate-of-change (ROC) enable Enables rate-of-change of frequency, step 2 No - Yes - 1 No 81D-2 ROC underfrequency pickup Pickup threshold for underfrequency for the rate-of-change of frequency element, step 2 40 - 70 Hz 0.01 40

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Description Range Units Step Default 81D-2 ROC frequency pickup Pickup threshold for rate-of-change of frequency, step 2 -10 - -0.5 Hz/s 0.01 -1 81D-2 ROC frequency time delay Pickup time delay for rate-of-change of frequency, step 2 0 - 300 s 0.01 0 81D-2 Dropout Time Drop-out time delay for rate-of-change of frequency, step 2 0 - 300 s 0.01 2 81D-3 Frequency rate-of-change (ROC) enable Enables rate-of-change of frequency, step 3 No - Yes - 1 No 81D-3 ROC underfrequency pickup Pickup threshold for underfrequency for the rate-of-change of frequency element, step 3 40 - 70 Hz 0.01 40 81D-3 ROC frequency pickup Pickup threshold for rate-of-change of frequency, step 3 -10 - -0.5 Hz/s 0.01 -1 81D-3 ROC frequency time delay Pickup time delay for rate-of-change of frequency, step 3 0 - 300 s 0.01 0 81D-3 Dropout Time Drop-out time delay for rate-of-change of frequency, step 3 0 - 300 s 0.01 2

7.4 CURRENT ELEMENTS

7.4.1 DIRECTIONAL ELEMENTS

Description Range Units Step Default 67P Phase characteristic angle Characteristic angle for phase directional elements 0 - 90 deg 1 45 67G Ground characteristic angle Characteristic angle for ground directional elements 0 - 90 deg 1 45 67Q Negative sequence characteristic angle Characteristic angle for negative sequence directional elements 0 - 90 deg 1 45 67P Minimum voltage Minimum polarizing voltage threshold for phase directional elements 0.05 - 10 V 0.01 0.2 67G Minimum voltage Minimum polarizing voltage threshold for ground directional elements 0.05 - 10 V 0.01 0.2 67Q Minimum voltage Minimum polarizing voltage threshold for negative sequence directional elements 0.05 - 10 V 0.01 0.2 Zero sequence voltage compensation Sets a factor to amplify available zero sequence voltage polarization level 0 - 50 - 0.01 0 Negative Sequence Voltage Compensation Sets a factor to amplify available zero sequence voltage polarization level 0 - 50 - 0.01 0 Loss of polarization block Select whether to block overcurrent element when polarization voltage is below set thresholds (Yes) or to allow the elements to operate non-directional (No). No - Yes - 1 No 67 transient block coordination time This is a timer setting for transient block logic when the directional overcurrent elements (50P and/or 50Q/G) are used in a permissive pilot scheme. 0 – 30 ms 1 0

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7.4.2 PHASE ELEMENTS

Description Range Units Step Default 50P-1 Phase instantaneous enable Enable instantaneous phase overcurrent element, step 1 No - Yes - 1 No 50P-1 Pickup Pick-up level for instantaneous phase overcurrent element, step 1 0.05 - 150 A 0.01 5 50P-1 Time delay Time delay for instantaneous phase overcurrent element, step 1 0 - 300 s 0.01 0 50P-1 Torque control Directional control of instantaneous phase overcurrent element, step 1

No Forward Reverse - 1 No

50P-1 Torque control type Selection to use directional element or Zone 2 for torque control of the instantaneous phase overcurrent element, step 1

67P Z2 - 1 67P

50P-2 Phase instantaneous enable Enable instantaneous phase overcurrent element, step 2 No - Yes - 1 No 50P-2 Pickup Pick-up level for instantaneous phase overcurrent element, step 2 0.05 - 150 A 0.01 5 50P-2 Time delay Time delay for instantaneous phase overcurrent element, step 2 0 - 300 s 0.01 0 50P-2 Torque control Directional control of instantaneous phase overcurrent element, step 2



67P Z2 - 1 67P

50P-3 Phase instantaneous enable Enable instantaneous phase overcurrent element, step 3 No - Yes - 1 No 50P-3 Pickup Pickup level for instantaneous phase overcurrent element, step 3 0.05 - 150 A 0.01 5 50P-3 Time delay Time delay for instantaneous phase overcurrent element, step 3 0 - 300 s 0.01 0 50P-3 Torque control Directional control of instantaneous phase overcurrent element, step 3

NO Forward Reverse - 1 NO


67P Z2 - 1 67P

51P1-1 Phase timeovercurrent enable Enable phase timeovercurrent element, step 1 No - Yes - 1 No 51P-1 Pickup Pickup level for phase timeovercurrent element, step 1 0.10 - 125 A 0.01 2

51P-1 Time curve Sets the time/current characteristic for phase timeovercurrent element, step 1

(see time curve selection below) - 1

Definite Time

51P-1 Time dial Set the time dial for the selected curve 0.05 - 10 - 0.01 1 51P-1 Time delay Sets the minimum time delay for the curves with Time Limit (TL) for the phase timeovercurrent element, step 1 0.05 - 300 s 0.01 0.05

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Description Range Units Step Default

51P-1 Torque control Directional control of phase timeovercurrent element, step 1


51P-1 Torque control type Selection to use directional element or Zone 2 for torque control of the phase timeovercurrent element, step 1

67P Z2 - 1 67P

51P-2 phase timeovercurrent enable Enable phase timeovercurrent element, step 2 No - Yes - 1 No 51P-2 Pickup Pickup level for phase timeovercurrent element, step 2 0.10 - 125 A 0.01 2

51P-2 Time Curve Sets the time/current characteristic for phase timeovercurrent element, step 2


Definite Time

51P-2 Time dial Set the time dial for the selected curve 0.05 - 10 - 0.01 1 51P-2 Time delay Sets the minimum time delay for the curves with Time Limit (TL) for the phase timeovercurrent element, step 2 0.05 - 300 s 0.01 0.05




67P Z2 - 1 67P

51P-3 Phase timeovercurrent enable Enable phase timeovercurrent element, step 3 No - Yes - 1 No 51P-3 Pickup Pickup level for phase timeovercurrent element, step 3 0.10 - 125 A 0.01 2

51P-3 Time curve Sets the time/current characteristic for phase timeovercurrent element, step 3


Definite Time

51P-3 Time dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1 51P-3 Time delay Sets the minimum time delay for the curves with Time Limit (TL) for the phase timeovercurrent element, step 3 0.05 - 300 s 0.01 0.05




67P Z2 - 1 67P

* Time Curve Selection Definite Time Inverse IEC Very Inverse IEC Extr. Inverse IEC Long Time Inv. IEC Short Time Inv. IEC Inverse IEC Minimum Time (TL) Very Inverse IEC Minimum Time (TL) Extr. Inverse IEC Minimum Time (TL) Long Time Inv. IEC Minimum Time (TL)

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Short Time Inv IEC Minimum Time (TL) Mod. Inverse IEEE Very Inverse IEEE Extr. Inverse IEEE Inverse IEEE Minimum Time (TL) Very Inverse IEEE Minimum Time (TL) Extr. Inverse IEEE Minimum Time (TL) Mod. Inverse ANSI Inverse ANSI Very Inverse ANSI Extr. Inverse ANSI Short Time Inv. ANSI Mod. Inverse ANSI Minimum Time (TL) Inverse ANSI Minimum Time (TL)

7.4.3 GROUND ELEMENTS

Description Range Units Step Default 50G-1 Instantaneous ground enable Enable instantaneous ground overcurrent element, step 1 No - Yes - 1 No 50G-1 Pickup Pickup level for instantaneous ground overcurrent element, step 1 0.600 - 150 A 0.01 5 50G-1 Time delay Time delay for instantaneous ground overcurrent element, step 1 0 - 300 s 0.01 0 50G-1 Torque control Directional control of instantaneous ground overcurrent element, step 1


50G-1 Torque control type Selection to use directional element or Zone 2 for torque control of the instantaneous ground overcurrent element, step 1

67G 67Q Z2G - 1 67G

50-G2 Instantaneous ground enable Enable instantaneous ground overcurrent element, step 2 No - Yes - 1 No 50G-2 Pickup Pickup level for instantaneous ground overcurrent element, step 2 0.600 - 150 A 0.01 5 50G-2 Time delay Time delay for instantaneous ground overcurrent element, step 2 0 - 300 s 0.01 0 50G-2 Torque control Directional control of instantaneous ground overcurrent element, step 2



67G 67Q Z2G - 1 67G

50G-3 Instantaneous ground enable Enable instantaneous ground overcurrent element, step 3 No - Yes - 1 No 50G-3 Pickup Pickup level for instantaneous ground overcurrent element, step 3 0.600 - 150 A 0.01 5 50G-3 Time delay Time delay for instantaneous ground overcurrent element, step 3 0 - 300 s 0.01 0 50G-3 Torque control Directional control of instantaneous ground overcurrent element, step 3



67G 67Q Z2G - 1 67G

51G-1 Ground timeovercurrent enable Enable ground timeovercurrent element, step 1 No - Yes - 1 No

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Description Range Units Step Default 51G-1 Pickup Pickup level for ground timeovercurrent element, step 1 0.600 - 125 A 0.01 1 51G-1 Time curve Sets the time/current characteristic for ground timeovercurrent element, step 1


Definite Time

51G-1 Time dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1 51G-1 Time delay Sets the minimum time delay for the curves with Time Limit (TL) for the ground timeovercurrent element, step 1 0.05 - 300 A 0.01 0.05 51G-1 Torque control type Selection to use directional element or Zone 2 for torque control of the ground timeovercurrent element, step 1

67G 67Q Z2G - 1 67G

51G-1 Torque control Directional control of ground timeovercurrent element, step 1


51G-2 Ground timeovercurrent enable Enable ground timeovercurrent element, step 2 No - Yes - 1 No 51G-2 Pickup Pickup level for ground timeovercurrent element, step 2 0.600 - 125 A 0.01 1 51G-2 Time curve Sets the time/current characteristic for ground timeovercurrent element, step 2


Definite Time

51G-2 Time dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1 51G-2 Time delay Sets the minimum time delay for the curves with Time Limit (TL) for the ground timeovercurrent element, step 2 0.05 - 300 s 0.01 0.05 51G-2 Torque control type Selection to use directional element or Zone 2 for torque control of the ground timeovercurrent element, step 2

67G 67Q Z2G - 1 67G



51G-3 Ground timeovercurrent enable Enable ground timeovercurrent element, step 3 No - Yes - 1 No 51G-3 Pickup Pickup level for ground timeovercurrent element, step 3 0.600 - 125 A 0.01 1 51G-3 Time curve Sets the time/current characteristic for ground timeovercurrent element, step 3


Definite Time

51G-3 Time dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1 51G-3 Time delay Sets the minimum time delay for the curves with Time Limit (TL) for the ground timeovercurrent element, step 3 0.05 - 300 s 0.01 0.05 51G-3 Torque control type Selection to use directional element or Zone 2 for torque control of the ground timeovercurrent element, step 3

67G 67Q Z2G - 1 67G



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* Time Curve Selection Definite Time Inverse IEC Very Inverse IEC Extr. Inverse IEC Long Time Inv. IEC Short Time Inv. IEC Inverse IEC Minimum Time (TL) Very Inverse IEC Minimum Time (TL) Extr. Inverse IEC Minimum Time (TL) Long Time Inv. IEC Minimum Time (TL) Short Time Inv IEC Minimum Time (TL) Mod. Inverse IEEE Very Inverse IEEE Extr. Inverse IEEE Inverse IEEE Minimum Time (TL) Very Inverse IEEE Minimum Time (TL) Extr. Inverse IEEE Minimum Time (TL) Mod. Inverse ANSI Inverse ANSI Very Inverse ANSI Extr. Inverse ANSI Short Time Inv. ANSI Mod. Inverse ANSI Minimum Time (TL) Inverse ANSI Minimum Time (TL)

7.4.4 NEGATIVE SEQUENCE ELEMENTS

Description Range Units Step Default 50Q-1 Instantaneous negative sequence enable Enable instantaneous negative sequence overcurrent element, step 1 No - Yes - 1 No 50Q-1 Pickup Pickup level for instantaneous negative sequence overcurrent element, step 1 0.25 - 150 A 0.01 10 50Q-1 Time delay Time delay for instantaneous negative sequence overcurrent element, step 1 0 - 300 s 0.01 0 50Q-1 Torque control Directional control of instantaneous negative sequence overcurrent element, step 1


50Q-1 Torque control type Selection to use directional element or Zone 2 for torque control of the instantaneous negative sequence overcurrent element, step 1

67Q Z2 - 1 67Q

50Q-2 Instantaneous negative sequence enable Enable instantaneous negative sequence overcurrent element, step 2 No - Yes - 1 No 50Q-2 Pickup Pickup level for instantaneous negative sequence overcurrent element, step 2 0.25 - 150 A 0.01 10 50Q-2 Time delay Time delay for instantaneous negative sequence overcurrent element, step 2 0 - 300 s 0.01 0

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Description Range Units Step Default 50Q-2 Torque control Directional control of instantaneous negative sequence overcurrent element, step 2

No Forward Reverse - 1 N0


67Q Z2 - 1 67Q

50Q-3 Instantaneous negative sequence enable Enable instantaneous negative sequence overcurrent element, step 3 No - Yes - 1 No 50Q-3 Pickup Pickup level for instantaneous negative sequence overcurrent element, step 3 0.25 - 150 A 0.01 10 50Q-3 Time delay Time delay for instantaneous negative sequence overcurrent element, step 3 0 - 300 s 0.01 0 50Q-3 Torque control Directional control of instantaneous negative sequence overcurrent element, step 3



67Q Z2 - 1 67Q

51Q-1 Negative sequence timeovercurrent enable Enable negative sequence timeovercurrent element, step 1 No - Yes - 1 No 51Q-1 Pickup Pickup level for negative sequence timeovercurrent element, step 1 0.50 - 25 A 0.01 2 51Q-1 Time curve Sets the time/current characteristic for the negative sequence timeovercurrent element, step 1

* (see time curve selection below) - 1

Definite Time

51Q-1 Time dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1 51Q-1 Fixed time Sets the minimum time delay for the curves with Time Limit (TL) for the negative sequence timeovercurrent element, step 1 0.05 - 300 s 0.01 0.05 51Q-1 Torque control type Selection to use directional element or Zone 2 for torque control of the negative sequence timeovercurrent element, step 1

67Q Z2 - 1 67Q

51Q-1 Torque control Directional control of negative sequence timeovercurrent element, step 1




Definite Time

51Q-2 Time dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1

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Description Range Units Step Default 51Q-2 Fixed time Sets the minimum time delay for the curves with Time Limit (TL) for the negative sequence timeovercurrent element, step 2 0.05 - 300 s 0.01 0.05 51Q-2 Torque control type Selection to use directional element or Zone 2 for torque control of the negative sequence timeovercurrent element, step 2

67Q Z2 - 1 67Q





Definite Time

51Q-3 Time dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1 51Q-3 Fixed time Sets the minimum time delay for the curves with Time Limit (TL) for the negative sequence timeovercurrent element, step 3 0.05 - 300 s 0.01 0.05 51Q-3 Torque control type Selection to use directional element or Zone 2 for torque control of the negative sequence timeovercurrent element, step 3

67Q Z2 - 1 67Q



* Time Curve Selection Definite Time Inverse IEC Very Inverse IEC Extr. Inverse IEC Long Time Inv. IEC Short Time Inv. IEC Inverse IEC Minimum Time (TL) Very Inverse IEC Minimum Time (TL) Extr. Inverse IEC Minimum Time (TL) Long Time Inv. IEC Minimum Time (TL) Short Time Inv IEC Minimum Time (TL) Mod. Inverse IEEE Very Inverse IEEE Extr. Inverse IEEE Inverse IEEE Minimum Time (TL) Very Inverse IEEE Minimum Time (TL) Extr. Inverse IEEE Minimum Time (TL) Mod. Inverse ANSI Inverse ANSI Very Inverse ANSI Extr. Inverse ANSI Short Time Inv. ANSI Mod. Inverse ANSI Minimum Time (TL) Inverse ANSI Minimum Time (TL)

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7.4.5 MISC. CURRENT ELEMENTS

Description Range Units Step Default 46 Open phase enable Enables the Broken Conductor (open phase) function No - Yes - 1 No 46 Pickup Pickup setting for broken conductor function. The Pickup level is set as I2/I1, the ratio of negative sequence and positive sequence current. 0.05 - 0.4 I2/I1 0.01 0.05 46 Time delay Time delay for trip for broken conductor 0.05 - 300 s 0.01 0.05 46 Minimum load Sets minimum load level for the broken conductor function. If the positive sequence current is below this level, the broken conductor function is blocked. 0.10 - 5 A 0.01 0.5 Forward Supervision 1-Ph Minimum operating current for forward phase- ground impedance zone operation 0.20 - 7.5 A 0.01 1 Forward Supervision 2-Ph Minimum operating current for forward phase- phase and three-phase impedance zone operation 0.20 - 7.5 A 0.01 1 Reverse Supervision 1-Ph Minimum operating current for reverse phase-ground impedance zone operation. When using Zone 4 reverse looking for directional comparison blocking (DCB) pilot schemes, the reverse sensitivity should be set higher (lower setting of the current supervision element) than the forward elements to ensure proper coordination. 0.20 - 7.5 A 0.01 1 Reverse Supervision 2-Ph Minimum operating current for forward phase-phase and three-phase impedance zone operation. When using Zone 4 reverse looking for directional comparison blocking (DCB) pilot schemes, the reverse sensitivity should be set higher (lower setting of the current supervision element) than the forward elements to ensure proper coordination. 0.20 - 7.5 A 0.01 1 49 Thermal image enable Enables the thermal image function No - Yes - 1 No 49 Heating constant Heating constant for the line. 0.50 - 300 min 0.01 0.50 49 Cooling constant Cooling constant for the line. 0.50 - 300 min 0.01 0.50 49 Maximum sustained current Maximum allowed continuous load current on the line 1 - 12.5 A 0.5 5 49 Alarm Level Thermal image alarm level 50 - 100 % 1 50 49 Thermal memory enable If thermal memory is set to Yes, the function retains the last calculated thermal level in memory and uses this as start level when the GARD 8000 is put back into service. No - Yes - 1 No 49 Reset threshold Thermal image reset level in % of alarm level. 50 - 100 % 1 80

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7.5 RECLOSER AND SYNC CHECK

7.5.1 RECLOSER Description Range Units Step Default In Service Enables recloser No - Yes - 1 No Reclosing Mode Selects single pole (1P), three pole (3P), single and three pole (1P/3P) or fault type dependent more reclosing. See ‘Description of Operation’ for details.

1P Mode, 3P Mode, 1P/3P Mode, Dependent Mode - 1 1P/3P

Reclose Attempts Number of reclose attempts, 1 – 3 1 - 3 - 1 3 1st reclose 25 supervision Enable synchro-check supervision of 1st reclose attemp


2nd reclose 25 supervision Enable synchro-check supervision of 2nd reclose attemp


3rd reclose 25 supervision Enable synchro-check supervision of 3rd reclose attemp


1st reclose 25 wait time enable Enable wait time for 1st synchro-check supervised recluse attempt. If disabled, synch-check condition is checked following the dead-time and it not fulfilled, the recloser goes to lock-out. If enabled, the recloser waits for the ‘Sync Wait Time’ before going into lock-out due to lack of synchronism.


2nd reclose 25 wait time enable Enable wait time for 2nd synchro-check supervised recluse attempt. If disabled, synch-check condition is checked following the dead-time and it not fulfilled, the recloser goes to lock-out. If enabled, the recloser waits for the ‘Sync Wait Time’ before going into lock-out due to lack of synchronism.


3rd reclose 25 wait time enable Enable wait time for 3rd synchro-check supervised reclose attempt. If disabled, synch-check condition is checked following the dead-time and it not fulfilled, the recloser goes to lock-out. If enabled, the recloser waits for the ‘Sync Wait Time’ before going into lock-out due to lack of synchronism.


1st 1Ph Reclose Cycle Time Dead-time for the 1st single pole attempt. 0.05 - 300 s 0.01 0.5 1st 3Ph Reclose Cycle Time Dead-time for the 1st three pole attempt. 0.05 - 300 s 0.01 0.5 2nd Reclose Cycle Time Dead-time for the 2nd attempt. 0.05 - 300 s 0.01 0.5 3rd Reclose Cycle Time Dead-time for the 3rd attempt. 0.05 - 300 s 0.01 0.5 25 Synch Check Wait Time Delay time for synchronizing check 0.05 - 300 s 0.01 5 Security Time Recloser reset time following closing of the circuit breaker. 0.05 - 300 s 0.01 10 Security Time for manual close Recloser reset time following manual closing of the circuit breaker. 0.05 - 300 s 0.01 5

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Description Range Units Step Default Start Time Recloser start timer. If this time expires before the recluse initiate signal resets, the circuit breaker opens and the TRIP signal resets, the recloser goes into lock-out. 0.07 - 0.6 s 0.01 0.2 Zone 1 RI Enable reclose initiate from Zone 1 trips


Zone 2 RI Enable reclose initiate from Zone 2 trips






50P-1 RI Enable reclose initiate from phase instantaneous overcurrent trips, Step 1






51P-1 RI Enable reclose initiate from phase timeovercurrent trips, Step 1






50G-1 RI Enable reclose initiate from ground instantaneous overcurrent trips, Step 1






51G-1 RI Enable reclose initiate from ground timeovercurrent trips, Step 1






50Q-1 RI Enable reclose initiate from negative sequence instantaneous overcurrent trips, Step 1






51Q-1 RI Enable reclose initiate from negative sequence time overcurrent trips, Step 1


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Description Range Units Step Default 51Q-2 RI Enable reclose initiate from negative sequence time overcurrent trips, Step 2


51Q-3 RI Enable reclose initiate from negative sequence time overcurrent trips, Step 3


46 Open Phase RI Enable reclose initiate for broken conductor trips


Remote Breaker Open Enable Enable reclose initiate from remote breaker open trips


7.5.2 SYNCH CHECK Description Range Units Step Default Synch Check Enable Enable synchro-check function No - Yes - 1 No Voltage Check Enable Enable voltage energizing function No - Yes - 1 No Voltage Difference Enable Enable voltage difference function No - Yes - 1 No Phase Difference Enable Enable phase difference function No - Yes - 1 No Frequency Difference Enable Enable frequency difference function No - Yes - 1 No Side A Voltage PU Sets side A voltage (line side) pick up. 20 - 70 V 1 20 Side B Voltage PU Sets side B voltage (bus side) pick up. 20 - 70 V 1 20 D BUS/D LINE Enable Dead Bus – Dead Line energizing


H BUS/D LINE Enable Hot Bus – Dead Line energizing


D BUS/H LINE Enable Dead Bus – Hot Line energizing


H BUS/H LINE Enable Hot Bus – Synch check


Internal/external synch check Selects internal or external synch check

External, Internal - 1 External

Reference voltage Selects bus voltage reference phase

Va, Vb, Vc - 1 Va

Max. Voltage difference Sets maximum allowed voltage difference between side A and side B 2 - 30 % 1 2 Max. Phase difference Sets maximum allowed phase difference between side A and side B 2 - 80 deg 1 2 Max. Frequency difference Sets maximum allowed frequency difference between side A and side B 0.01 - 2 Hz 0.01 0.01 Synch Check Delay Sets delay time for synchro-check function 0 - 300 s 0.01 0 LOP Synch Check Block Enables block of synchro-check function for loss-of-potential conditions No - Yes - 1 No

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7.6 BREAKER FAILURE

Description Range Units Step Default Trip output seal-in Enables trip seal for breaker failure relay trips No - Yes - 1 No Breaker opening fail time delay Time following breaker open command until fail to open condition is declared 0.02 - 5 s 0.01 0.02 Breaker closing fail time delay Time following breaker close command until fail to close condition is declared 0.02 - 5 s 0.01 0.02 Manual close synch check supervision Enables synchro-check supervision of manual breaker close command No - Yes - 1 No 50BF Breaker failure enable Enables breaker failure function No - Yes - 1 No Single phase pickup Pick up level on per phase basis for single pole trip 0.10 – 12 A 0.01 1 Three phase pickup Pickup level on per phase basis for three pole trip 0.10 - 12 A 0.01 1 1 Pole BF delay Single pole breaker failure trip delay 0.05 - 2 s 0.01 0.5 3 Pole BF delay Three pole breaker failure trip delay 0.05 - 2 s 0.01 0.5 1 Pole retrip delay Time delay for single pole re-trip breaker failure function. 0.05 - 2 s 0.01 0.5 3 Pole retrip delay Time delay for three pole re-trip breaker failure function. 0.05 - 2 s 0.01 0.5 Remote open breaker detection enable Enables loss-of-load function No - Yes - 1 No Remote open breaker time delay Time delay for loss-of-load trip 0 - 2000 ms 1 0 Detection by capacitive current For long lines where there is sufficient capacitive line charging current, this current can be used to supervise the loss-of-load function. In that case, use the setting ‘Yes’ No - Yes - 1 No Min current level Minimum current level for line charging current. When the measured current is below this value, the breaker pole is determined to be open. 0 - 5 A 0.01 0.75

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7.7 VOLTAGE ELEMENTS Description Range Units Step Default 59-1 Phase Overvoltage Enable Enables phase overvoltage element, step 1 No - Yes - 1 No 59-1 Pickup Pickup level for phase overvoltage, step 1 20 - 300 V 0.01 70 59-1 Time Delay Time delay for phase overvoltage, step 1 0 - 300 s 0.01 0 59-1 Output Logic Selects if the three phase voltage elements should be connected in series (AND) or in parallel (OR)

OR AND - 1 OR

59-2 Phase Overvoltage Enable Enables phase overvoltage element, step 2 No - Yes - 1 No 59-2 Pickup Pickup level for phase overvoltage, step 2 20 - 300 V 0.01 70 59-2 Time Delay Time delay for phase overvoltage, step 2 0 - 300 s 0.01 0 59-2 Output Logic Selects if the three phase voltage elements should be connected in series (AND) or in parallel (OR)

OR AND - 1 OR

59-3 Phase Overvoltage Enable Enables phase overvoltage element, step 3 No - Yes - 1 No 59-3 Pickup Pickup level for phase overvoltage, step 3 20 - 300 V 0.01 70 59-3 Time Delay Time delay for phase overvoltage, step 3 0 - 300 s 0.01 0 59-3 Output Logic Selects if the three phase voltage elements should be connected in series (AND) or in parallel (OR)

OR AND - 1 OR

59G-1 Ground Overvoltage Enable Enables ground overvoltage element, step 1 No - Yes - 1 No 59G-1 Pickup Pickup level for ground overvoltage, step 1 2 - 150 V 0.01 10 59G-1 Time Delay Time delay for ground overvoltage, step 1 0 - 300 s 0.01 0 59G-2 Ground Overvoltage Enable Enables ground overvoltage element, step 2 No - Yes - 1 No 59G-2 Pickup Pickup level for ground overvoltage, step 2 2 - 150 V 0.01 10 59G-2 Time Delay Time delay for ground overvoltage, step 2 0 - 300 s 0.01 0 27-1 Phase Undervoltage Enable Enables phase undervoltage element, step 1 No - Yes - 1 No 27-1 Pickup Pickup level for phase undervoltage, step 1 10 - 300 V 0.01 40 27-1 Time Delay Time delay for phase undervoltage, step 1 0 - 300 s 0.01 0 27-1 Output Logic Selects if the three phase voltage elements should be connected in series (AND) or in parallel (OR)

OR AND - 1 OR

27-2 Phase Undervoltage Enable Enables phase undervoltage element, step 2 No - Yes - 1 No 27-2 Pickup Pickup level for phase undervoltage, step 2 10 - 300 V 0.01 40

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Description Range Units Step Default 27-2 Time Delay Time delay for phase undervoltage, step 2 0 - 300 s 0.01 0 27-2 Output Logic Selects if the three phase voltage elements should be connected in series (AND) or in parallel (OR)

OR AND - 1 OR

27-3 Phase Undervoltage Enable Enables phase undervoltage element, step 3 No - Yes - 1 No 27-3 Pickup Pickup level for phase undervoltage, step 3 10 - 300 V 0.01 40 27-3 Time Delay Time delay for phase undervoltage, step 3 0 - 300 s 0.01 0 27-3 Output Logic Selects if the three phase voltage elements should be connected in series (AND) or in parallel (OR)

OR AND - 1 OR

27P Drop-Out Ratio Drop-out ratio for the phase undervoltage elements 101 - 150 % 1 105 59P Drop-Out Ratio Drop-out ratio for the phase overvoltage elements 50 - 99 % 1 95 59G Drop-Out Ratio Drop-out ratio for the ground overvoltage elements 50 - 99 % 1 95

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7.8 FAULT RECORDER (DFR) Description Range Units Step Default Trip Required Determines whether a digital fault record should be saved following a trip only (Yes) or from Pickup of the trig elements (No). No - Yes - 1 No Continuous Mode If set to ‘Yes’, the DFR starts when a trig is activated and keeps recording until the trig elements reset. When set to ‘No’, the record starts when a trip is activated and keeps recording until the pre-set ‘Length’ time is reached. No - Yes - 1 No Pretrig Length Number of pre-fault cycles in the record. 0 - 25 cycls 1 2 Total length Number of fault cycles in the record when ‘Continuous Mode’ is set to ‘No’. 5 - 240 cycls 1 8 VA Enables recording of analog channel voltage phase A No - Yes - - Yes VB Enables recording of analog channel voltage phase B No - Yes - - Yes VC Enables recording of analog channel voltage phase C No - Yes - - Yes VSYNC Enables recording of analog channel voltage synchronizing input No - Yes - - No IA Enables recording of analog channel current phase A No - Yes - - Yes IB Enables recording of analog channel current phase B No - Yes - - Yes IC Enables recording of analog channel current phase C No - Yes - - Yes IPOL Enables recording of analog channel current polarizing input No - Yes - - No IGPAR Enables recording of analog channel neutral current from parallel line No - Yes - - No

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7.9 OSCILLOGRAPHY MASK Description Range Units Step Default 50P-1 Instantaneous phase overcurrent, step 1 No - Yes - - No 50P-2 Instantaneous phase overcurrent, step 2 No - Yes - - No 50P-3 Instantaneous phase overcurrent, step 3 No - Yes - - No 50G-1 Instantaneous ground overcurrent, step 1 No - Yes - - No 50G-2 Instantaneous ground overcurrent, step 2 No - Yes - - No 50G-3 Instantaneous ground overcurrent, step 3 No - Yes - - No 50Q-1 Instantaneous negative sequence overcurrent, step 1 No - Yes No 50Q-2 Instantaneous negative sequence overcurrent, step 2 No - Yes No 50Q-3 Instantaneous negative sequence overcurrent, step 3 No - Yes No 51P-1 Phase time overcurrent, step 1 No - Yes No 51P-2 Phase time overcurrent, step 2 No - Yes No 51P-3 Phase time overcurrent, step 3 No - Yes No 51G-1 Ground time overcurrent, step 1 No - Yes No 51G-2 Ground time overcurrent, step 2 No - Yes No 51G-3 Ground time overcurrent, step 3 No - Yes No 51Q-1 Negative sequence time overcurrent, step 1 No - Yes No 51Q-2 Negative sequence time overcurrent, step 2 No - Yes No 51Q-3 Negative sequence time overcurrent, step 3 No - Yes No 27P-1 Phase undervoltage, step 1 No - Yes No 27P-2 Phase undervoltage, step 2 No - Yes No 27P-3 Phase undervoltage, step 3 No - Yes No 59P-1 Phase overvoltage, step 1 No - Yes No 59P-2 Phase overvoltage, step 2 No - Yes No 59P-3 Phase overvoltage, step 3 No - Yes No 59G-1 Ground overvoltage, step 1 No - Yes No

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Description Range Units Step Default 59G-2 Ground overvoltage, step 2 No - Yes No 81-1 Underfrequency Underfrequency, step 1 No - Yes No 81-2 Underfrequency Underfrequency, step 2 No - Yes No 81-3 Underfrequency Underfrequency, step 3 No - Yes No 81-1 Overfrequency Overfrequency, step 1 No - Yes No 81-2 Overfrequency Overfrequency, step 2 No - Yes No 81-3 Overfrequency Overfrequency, step 3 No - Yes No 81-1 Rate-of-change of frequency Rate-of-change of frequency, step 1 No - Yes No 81-2 Rate-of-change of frequency Rate-of-change of frequency, step 2 No - Yes No 81-3 Rate-of-change of frequency Rate-of-change of frequency, step 3 No - Yes No Load Restriction Load restriction characteristic picked up No - Yes No Open phase 46 Broken conductor/open phase No - Yes No Thermal image Thermal image alarm No - Yes No External trip External trip No - Yes No Z1 phase pickup Zone 1 phase element Pickup No - Yes Yes Z1 ground pickup Zone 1 ground element Pickup No - Yes Yes Z2 phase pickup Zone 2 phase element Pickup No - Yes Yes Z2 ground pickup Zone 2 ground element Pickup No - Yes Yes Z3 phase pickup Zone 3 phase element Pickup No - Yes Yes Z3 ground pickup Zone 3 ground element Pickup No - Yes Yes Z4 phase pickup Zone 4 phase element Pickup No - Yes Yes Z4 ground pickup Zone 4 ground element Pickup No - Yes Yes

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7.10 SOE MASK The signals in the table below are available as triggers for Sequence of Event records. If the setting is ‘Yes’, pickup of the signal will trigger a SOE record. If the setting is ‘No’, no SOE will be triggered by the logical signal.

Description Range Units Step Default System non-critical error No - Yes - 1 No System critical error No - Yes - 1 No Change of settings No - Yes - 1 No A 51P-1 pickup No - Yes - 1 No B 51P-1 pickup No - Yes - 1 No C 51P-1 pickup No - Yes - 1 No 51G-1 pickup No - Yes - 1 No A 50P-1 pickup No - Yes - 1 No B 50P-1 pickup No - Yes - 1 No C 50P-1 pickup No - Yes - 1 No 50G-1 pickup No - Yes - 1 No A 51P-1 trip No - Yes - 1 No B 51P-1 trip No - Yes - 1 No C 51P-1 trip No - Yes - 1 No 51G-1 trip No - Yes - 1 No A 50P-1 trip No - Yes - 1 No B 50P-1 trip No - Yes - 1 No C 50P-1 trip No - Yes - 1 No 50G-1 trip No - Yes - 1 No Open phase pickup No - Yes - 1 No Open phase trip No - Yes - 1 No Breaker current alarm No - Yes - 1 No BG Z4 pickup No - Yes - 1 No BG Z3 pickup No - Yes - 1 No BG Z2 pickup No - Yes - 1 No BG Z1 pickup No - Yes - 1 No AG Z4 pickup No - Yes - 1 No AG Z3 pickup No - Yes - 1 No AG Z2 pickup No - Yes - 1 No AG Z1 pickup No - Yes - 1 No AB Z4 pickup No - Yes - 1 No AB Z3 pickup No - Yes - 1 No AB Z2 pickup No - Yes - 1 No AB Z1 pickup No - Yes - 1 No CG Z4 pickup No - Yes - 1 No CG Z3 pickup No - Yes - 1 No CG Z2 pickup No - Yes - 1 No CG Z1 pickup No - Yes - 1 No CA Z4 pickup No - Yes - 1 No CA Z3 pickup No - Yes - 1 No CA Z2 pickup No - Yes - 1 No CA Z1 pickup No - Yes - 1 No BC Z4 pickup No - Yes - 1 No BC Z3 pickup No - Yes - 1 No BC Z2 pickup No - Yes - 1 No BC Z1 pickup No - Yes - 1 No

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Description Range Units Step Default Z4 step distance trip No - Yes - 1 Yes Z3 step distance trip No - Yes - 1 Yes Z2 step distance trip No - Yes - 1 Yes Z1 step distance trip No - Yes - 1 Yes C pole trip No - Yes - 1 No B pole trip No - Yes - 1 No A pole trip No - Yes - 1 No Close into fault No - Yes - 1 No LOP detector No - Yes - 1 No Distance channel start No - Yes - 1 No Distance pilot trip No - Yes - 1 No Weak infeed trip distance No - Yes - 1 No Power swing block No - Yes - 1 No Remote breaker open detector No - Yes - 1 No Fault detector No - Yes - 1 No Distance channel stop No - Yes - 1 No Trip No - Yes - 1 No Thermal image alarm No - Yes - 1 No Thermal image trip No - Yes - 1 No Recloser lock out No - Yes - 1 No Reclose command No - Yes - 1 No Excessive number of trips No - Yes - 1 No Close command No - Yes - 1 No Open command No - Yes - 1 No A 50P-2 pickup No - Yes - 1 No B 50P-2 pickup No - Yes - 1 No C 50P-2 pickup No - Yes - 1 No 50G-2 pickup No - Yes - 1 No 50Q-1 pickup No - Yes - 1 No 50Q-2 pickup No - Yes - 1 No A 50P-2 trip No - Yes - 1 No B 50P-2 trip No - Yes - 1 No C 50P-2 trip No - Yes - 1 No 50G-2 trip No - Yes - 1 No 50Q-1 trip No - Yes - 1 No 50Q-2 trip No - Yes - 1 No 50Q-3 pickup No - Yes - 1 No 50Q-3 trip No - Yes - 1 No Stub bus pickup No - Yes - 1 No Stub bus trip No - Yes - 1 No A 50P-3 pickup No - Yes - 1 No B 50P-3 pickup No - Yes - 1 No C 50P-3 pickup No - Yes - 1 No 50G-3 pickup No - Yes - 1 No A 50P-3 trip No - Yes - 1 No B 50P-3 trip No - Yes - 1 No C 50P-3 trip No - Yes - 1 No 50G-3 trip No - Yes - 1 No 51Q-1 pickup No - Yes - 1 No A 51P-2 pickup No - Yes - 1 No B 51P-2 pickup No - Yes - 1 No C 51P-2 pickup No - Yes - 1 No 51G-2 pickup No - Yes - 1 No

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Description Range Units Step Default 51Q-2 pickup No - Yes - 1 No A 51P-3 pickup No - Yes - 1 No B 51P-3 pickup No - Yes - 1 No C 51P-3 pickup No - Yes - 1 No 51G-3 pickup No - Yes - 1 No 51Q-3 pickup No - Yes - 1 No 51Q-1 trip No - Yes - 1 No A 51P-2 trip No - Yes - 1 No B 51P-2 trip No - Yes - 1 No C 51P-2 trip No - Yes - 1 No 51G-2 trip No - Yes - 1 No 51 Q-2 trip No - Yes - 1 No A 51P-3 trip No - Yes - 1 No B 51P-3 trip No - Yes - 1 No C 51P-3 trip No - Yes - 1 No 51G-3 trip No - Yes - 1 No 51Q-3 trip No - Yes - 1 No A 27-1 trip No - Yes - 1 No B 27-1 trip No - Yes - 1 No C 27-1 trip No - Yes - 1 No Three phase 27P-1 trip No - Yes - 1 No A 27-2 trip No - Yes - 1 No B 27-2 trip No - Yes - 1 No C 27-2 trip No - Yes - 1 No Three phase 27P-2 trip No - Yes - 1 No A 27-3 trip No - Yes - 1 No B 27-3 trip No - Yes - 1 No C 27-3 trip No - Yes - 1 No Three phase 27P-3 trip No - Yes - 1 No A 59P-1 pickup No - Yes - 1 No B 59P-1 pickup No - Yes - 1 No C 59P-1 pickup No - Yes - 1 No Three phase 59P-1 pickup No - Yes - 1 No A 59P-2 pickup No - Yes - 1 No B 59P-2 pickup No - Yes - 1 No C 59P-2 pickup No - Yes - 1 No Three phase 59P-2 pickup No - Yes - 1 No A 59P-3 pickup No - Yes - 1 No B 59P-3 pickup No - Yes - 1 No C 59P-3 pickup No - Yes - 1 No Three phase 59P-3 pickup No - Yes - 1 No 59G-1 pickup No - Yes - 1 No 59G-2 pickup No - Yes - 1 No A 59P-1 trip No - Yes - 1 No B 59P-1 trip No - Yes - 1 No C 59P-1 trip No - Yes - 1 No Three phase 59P-1 trip No - Yes - 1 No A 59P-2 trip No - Yes - 1 No B 59P-2 trip No - Yes - 1 No C 59P-2 trip No - Yes - 1 No Three phase 59P-2 trip No - Yes - 1 No A 59P-3 trip No - Yes - 1 No B 59P-3 trip No - Yes - 1 No

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Description Range Units Step Default C 59P-3 trip No - Yes - 1 No Three phase 59P-3 trip No - Yes - 1 No 59G-1 trip No - Yes - 1 No 59G-2 trip No - Yes - 1 No 81-1 overfrequency pickup No - Yes - 1 No 81-2 overfrequency pickup No - Yes - 1 No 81-3 overfrequency pickup No - Yes - 1 No 81-1 underfrequency pickup No - Yes - 1 No 81-2 underfrequency pickup No - Yes - 1 No 81-3 underfrequency pickup No - Yes - 1 No 81-1 rate-of-change of frequency pickup No - Yes - 1 No 81-2 rate-of-change of frequency pickup No - Yes - 1 No 81-3 rate-of-change of frequency pickup No - Yes - 1 No 81-1 overfrequency trip No - Yes - 1 No 81-2 overfrequency trip No - Yes - 1 No 81-3 overfrequency trip No - Yes - 1 No 81-1 underfrequency trip No - Yes - 1 No 81-2 underfrequency trip No - Yes - 1 No 81-3 underfrequency trip No - Yes - 1 No 81-1 rate-of-change of frequency trip No - Yes - 1 No 81-2 rate-of-change of frequency trip No - Yes - 1 No 81-3 rate-of-change of frequency trip No - Yes - 1 No Settings group 1 by BI No - Yes - 1 No Settings group 2 by BI No - Yes - 1 No Settings group 3 by BI No - Yes - 1 No Settings group 4 by BI No - Yes - 1 No Settings group 1 by comms No - Yes - 1 No Settings group 2 by comms No - Yes - 1 No Settings group 3 by comms No - Yes - 1 No Settings group 4 by comms No - Yes - 1 No 50BF breaker failure pickup No - Yes - 1 No A retrip No - Yes - 1 No B retrip No - Yes - 1 No C retrip No - Yes - 1 No Three phase retrip No - Yes - 1 No Z1 fault No - Yes - 1 Yes Z2 fault No - Yes - 1 Yes Z3 fault No - Yes - 1 Yes Z4 fault No - Yes - 1 Yes Z1-P pickup No - Yes - 1 Yes Z1-G pickup No - Yes - 1 Yes

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Distance Relay Setting Examples


SECTION 8. DISTANCE RELAY SETTING EXAMPLES

8.1 GARD 8000 21L SETTING EXAMPLES – STEPPED DISTANCE

8.1.1 LINE Nominal voltage 230 kV Nominal current 5 A Frequency 60 Hz Line length 54 miles Positive sequence Z1L Line impedance (primary ohms) 41.33@85 degrees Zero sequence Z0L Line impedance (primary ohms) 145.48@74 degrees Local source impedance Z1SL, positive sequence (primary ohms) 50@86 degrees Local source impedance Z0SL, zero sequence (primary ohms) 50@86 degrees Remote source impedance Z1SR, positive sequence (primary ohms) 50@86 degrees Remote source impedance Z0Sr, zero sequence (primary ohms) 50@86 degrees PT ratio 230 kV:115V = 2000 CT ratio 1000:5 = 200 Maximum load current (primary A) 890

8.1.2 CONVERSION TO SECONDARY VALUES

Zsec = Zpri .CTratioPTratio = Zpri .

2002000 = Zpri . 0.1

Z1Lsec = 0.1 · 41.33√85º = 4.13√85º Z0Lsec = 0.1 · 145.48√74º = 14.55√74º Zsource = 0.1 · 50√86º = 5.00√85º

IprimaryCTratio =

890200 = 4.45 AMaximum load current (secondary) =

Z0LZ1L =

14.554.13 = 3.52k0 (Zone 1, 2, 3 and 4) =

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8.1.3 CCVT SETTING The General Settings include an option to enable or disable the CCVT filter. The filter is not required if the SIR is less than five, where SIR is defined as the ratio of the local source impedance to the relay reach. The CCVT filter is only applied to the underreaching Zone 1, as applicable, to prevent possible overreach for CCVT transients.

SIR = 5Z1SL0.8 .Z1L

= 0.8 4.13. = 1.5 < 5

8.1.4 GENERAL SETTINGS Description Range Units Step Actual

Yes Enable distance protection Sets all distance protection module functions ON or OFF

No - Yes - 1

RX Logic Bus Start Bit Used by system logic. Factory set.

3-511 - 1 300

RX Logic Bus Length Used by system logic. Factory set.

0-64 - 1 64

TX Logic Bus Start Bit Used by system logic. Factory set.

3-511 - 1 364

TX Logic Bus Length Used by system logic. Factory set.

0-64 - 1 64

Active Setting Group Determines setting group in use by the distance protection module

Group 1 Group 2 Group 3 Group 4

- 1 Group 1

200 Line CT ratio Current transformer ratio for the protected line. For example, a 2000/5 A CT has the ratio 400.

1 - 3000 - 1

2000 Line PT Ratio Voltage transformer ratio for the protected line. For example, a 115,000/120 V PT has the ratio 1125.

1 - 10000 - 1

Bus PT Ratio Voltage transformer ratio for a bus voltage used for the synchro-check function. For example, a 115,000/120 V PT has the ratio 1125.

1 - 10000 - 1 1

Polarization CT ratio Current transformer ratio for a CT used for current ground polarization.

1 - 3000 - 1 1

Parallel line CT Ratio Current transformer ratio for the CT on a parallel line used for mutual coupling compensation for the fault locator.

1 - 3000 - 1 1

Excessive Trips Maximum number of breaker trips during a half hour interval. Performed by the breaker monitoring function.

1 - 40 - 1 40

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Description Range Units Step Actual

I² Sum Alarm Alarm level for accumulated breaking current.

0 - 99999.99 kA² 0.01 99999.99

I² Dropout Value The dropout value is used to reset the counter following breaker maintenance (then set to 0). It can also be set to a value corresponding to estimated breaking current at the time GARD 8000 is put into service, enabling a ‘start’ value for the counter other than 0.

0 - 99999.99 kA² 0.01 0

No Capacitive VT Enable (Yes) or disable (No) the use of CCVT filter for the distance relay.

No - Yes - 1

8.1.5 LINE PROTECTION SYSTEM SETTINGS

8.1.5.1 TRIP MASK VERSUS ELEMENT ENABLE Most functions have two enable settings. One in the Line Protection System Settings, which is the Trip Mask and another on the corresponding element setting page, which is the element enable setting. For example, the Zone 2 element setting is on the page for “Distance Protection” “Zone 1 to 4.” The below figure is attempting to explain the difference between the Trip Mask and Element enable settings. The figure uses the example of Zone 2. The Zone 2 element can have two functions; independent trip after set Zone 2 time delay, and/or pilot operation through the selected pilot logic. The element itself (Zone 2 Enable on the Zone 1 to 4 page) needs to be enabled for either of these functions to operate. However, the Line Protection System Settings “Ground unit Z2” and “Phase unit Z2” can be disabled, and pilot operation will still take place. Only if time-delayed independent Zone 2 trip is desired, should the Distance Protection System settings be enabled.

Distance protection trip

Zone 2 Phase

Zone 2 Ground

Phase Units Z 2

Enable

Ground Units Z 2

Line Protection System Settings

Distance ElementsZone 1 to Zone 4

Zone 2 Enable

Pilot Logic

Enable

Enable

Zone 2 phase timer

Zone 2 ground timer

Yes

Yes

Yes

Figure 8-1. Trip Mask Enable and Element Enable (Stepped Distance)

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Note that in the “Line Protection System Settings” below, only settings related to stepped distance (Zone 1, Zone 2 and Zone 3) operation have been entered and enabled. The Zone 4 element is enabled for measurement only. This means that the “Line Protection System Setting” for Zone 4 should be “disabled while the element setting in “Distance Elements” Zone 1 to 4” should be enabled. This allows the element to measure and trigger fault records, but it will not issue a trip.

Description Range Units Step Actual Line Pos.Seq. Impedance Magnitude Positive sequence impedance magnitude for the protected line in secondary ohms 0.01 - 100 Ohm 0.01 4.13 Line Pos.Seq. Impedance Angle Positive sequence impedance angle for the protected line in degrees 5 - 90 deg 1 85 Pos. Seq. Angle Zone 2 Positive sequence impedance angle for the protected line sections for Zone 2 in degrees 5 - 90 deg 1 85 Pos. Seq. Angle Zone 3 Positive sequence impedance angle for the protected line sections for Zone 3 in degrees 5 - 90 deg 1 85 Pos. Seq. Angle Zone 4 Positive sequence impedance angle for the protected line sections for Zone 4 in degrees 5 - 90 deg 1 85 Zone 1 k0 Factor Zero sequence compensation factor magnitude for Zone 1. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 3.52 Line Zero Seq. Impedance Angle Zero sequence impedance angle for the protected line in degrees 5 - 90 deg 1 74 Zone 2 k0 Factor Zero sequence compensation factor magnitude for Zone 2. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 3.52 Zone 2 Zero Seq. Angle Zero sequence impedance (Z0) angle in degrees for Zone 2. 5 - 90 deg 1 74 Zone 3 k0 Factor Zero sequence compensation factor magnitude for Zone 3. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 3.52 Zone 3 Zero Seq. Angle Zero sequence impedance (Z0) angle in degrees for Zone 3. 5 - 90 deg 1 74 Zone 4 k0 Factor Zero sequence compensation factor magnitude for Zone 4. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 3.52 Zone 4 Zero Seq. Angle Zero sequence impedance (Z0) angle in degrees for Zone 4. 5 - 90 deg 1 74 Local Pos.Seq. Source Impedance Magnitude Positive sequence impedance magnitude for the local source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 5.00 Local Pos.Seq. Source Impedance Angle Positive sequence impedance angle for the local source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 85

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Description Range Units Step Actual Local Zero Seq. Source Impedance Magnitude Zero sequence impedance magnitude for the local source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 5.00 Local Zero Seq. Source Impedance Angle Zero sequence impedance angle for the local source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 85 Remote Pos.Seq. Source Impedance Magnitude Positive sequence impedance magnitude for the remote source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 5.00 Remote Pos.Seq. Source Impedance Angle Positive sequence impedance angle for the remote source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 85 Remote Zero Seq. Source Impedance Magnitude Zero sequence impedance magnitude for the remote source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 5.00 Remote Zero Seq. Source Impedance Angle Zero sequence impedance angle for the remote source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 85 Parallel Line Pos.Seq. Magnitude Positive sequence impedance magnitude for a parallel line in secondary ohms. Used for mutual compensation for the fault locator.

0.01 - 10000 Ohm 0.01 1.25

Parallel Line Pos. Seq, Angle Positive sequence impedance angle for a parallel line in degrees. Used for mutual compensation for the fault locator. 5 - 90 deg 1 75 Parallel Line Zero Seq. Magnitude Zero sequence impedance magnitude for a parallel line in secondary ohms. Used for mutual compensation for the fault locator.

0.01 - 10000 Ohm 0.01 1.25

Parallel Line Zero Seq. Angle Zero sequence impedance angle for a parallel line in degrees. Used for mutual compensation for the fault locator. 5 - 90 deg 1 75 Fault Locator Units Determines display of fault locator calculation in % (% of Length) or in kilometers/miles (Length Units) as set for the parameter ‘Length Units’.

Length Units % of Length - 1 % of Length

Line Length Total line length in kilometers or miles, as set for the parameter ‘Length Units’. 0 - 400 - 0.01 100 Indication Zone Determines if fault location should be calculated and displayed for faults on the protected line only (In) or for all faults that are detected by the distance relay (In & Out)


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Description Range Units Step Actual Length Units Determines display of fault locator calculation in kilometers or miles, when parameter ‘Fault Locator Units’ is set to ‘Length Units’.

Kilometers Miles - 1 Miles

Mutual Coupl. Factor Mutual coupling factor to a parallel line for mutual compensation of the fault locator. The coupling factor is determined as |Z0/Zm0| 0 - 10 Ohm 0.01 0 Mutual Coupl. Angle Mutual coupling angle to a parallel line for mutual compensation of the fault locator. The angle is determined as LZ0 - LZm0 5 - 90 deg 1 25 Mut Coupl. Comp. Enable Turns mutual coupling compensation ON or OFF. For mutual coupling, the neutral ct current from the parallel line needs to be wired into the GARD 8000 relay. No - Yes - 1 No Pick Up Report This setting determines whether fault records should be triggered from pick-up of any element (YES) or following a trip only (NO). No - Yes - 1 Yes Three-Phase Trip Selects 3-pole tripping (Yes) or single pole tripping (No) No – Yes - 1 Yes 1 Pole Trip 67G Selects 3-pole tripping (No) or single pole tripping (Yes) from the directional ground element No – Yes - 1 No Ground Units Z1 Enables trip operation by Zone 1 ground distance units


Phase Units Z1 Enables trip operation by Zone 1 phase distance units


Ground Units Z2 Enables trip operation by Zone 2 ground distance units












Remote Breaker Open Enables the remote open breaker logic.




Stub Bus Prot. Enables the stub bus protection logic.


Thermal Image Enables the thermal image element.


Open Phase Detector Enables open phase/broken conductor detector logic.


Pole Discrepancy Enables the pole discrepancy logic.


Out of Step Trip Enables out of step trip operation.




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Description Range Units Step Actual 50P-2 Enables trip by Instantaneous Phase Overcurrent, step 2.


















































81 UNDFREQ1 Enables trip by Underfrequency, step 1.


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Description Range Units Step Actual 81 UNDFREQ2 Enables trip by Underfrequency, step 2.




81 OVERFREQ1 Enables trip by Overfrequency, step 1.






81 FREQCHG1 Enables trip by Rate-of-change of Frequency, step 1.






8.1.6 REACH SETTINGS Pilot scheme settings will be discussed in further detail below. The following is an example of a basic stepped distance setting with Z1 set to 80% of line impedance, Z2 set to 120%, Z3 set to 200% and Z4 set to 50% in the reverse direction. Z1, Z2 and Z3 are set for trip (after corresponding time delay). Zone 4 is enabled for measurement only, intended for use as a fault trigger, but not trip. Zone 1 reach 80% of ZL1 = 0.8 · 4.13 = 3.30 Time delay = 0 Zone 2 reach 120% of ZL1 = 1.2 · 4.13 = 4.96 Time delay = 300 ms (0.3 s) Zone 3 reach 200% of ZL1 = 2 · 4.13 = 8.26 Time delay = 800 ms (0.8 s) Zone 4 reach (reverse, used for indication only in this stepped distance scheme) 50% of ZL1 = 0.5 · 4.13 = 2.07

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8.1.7 DISTANCE ELEMENTS – ZONE 1 TO ZONE 4 SETTINGS Description Range Units Step Actual Zone 1 Enable

Yes Enable operation of Zone 1 distance No – Yes - 1 Zone 1 direction Reverse

Forward Forward - 1 Zone 1 measuring direction, forward or reverse. Zone 1 reach Zone 1 reactive reach in secondary ohms, at set characteristic line angle. 0.01 - 100 Ohm 0.01 3.30 1-Ph Resistive Limit Zone 1 Resistive reach in secondary ohms for Zone 1 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 – 100 - 0.01 4 2-Ph Resistive Limit Zone 1 Resistive reach in secondary ohms for Zone 1 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 1 ground timer Zone 1 ground elements time delay 0 - 300 s 0.01 0 Zone 1 phase timer Zone 1 phase elements time delay 0 - 300 s 0.01 0 Zone 1 quad tilt time delay Time delay for the load compensation of the reactive quadrilateral line. After this time, the load compensation is turned off and the line reverts to being parallel with the R-axis. Recommended time delay is 0.08 s (80 ms). 0 - 0.5 s 0.01 0 Zone 2 Enable Enable operation of Zone 2 distance No – Yes - 1 Yes Zone 2 direction Zone 2 measuring direction, forward or reverse.


Zone 2 reach Zone 2 reactive reach in secondary ohms, at set characteristic line angle. 0.01 - 100 Ohm 0.01 4.96 1-Ph Resistive Limit Zone 2 Resistive reach in secondary ohms for Zone 2 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 - 100 - 0.01 4 2-Ph Resistive Limit Zone 2 Resistive reach in secondary ohms for Zone 2 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 2 ground timer Zone 2 ground elements time delay 0 - 300 s 0.01 0.3 Zone 2 phase timer Zone 2 phase elements time delay 0 - 300 s 0.01 0.3

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Description Range Units Step Actual Zone 3 Enable Enable operation of Zone 3 distance No – Yes - 1 Yes Zone 3 direction Zone 3 measuring direction, forward or reverse.


Zone 3 reach Zone 3 reactive reach in secondary ohms, at set characteristic line angle. 0.01 – 100 Ohm 0.01 8.26 1-Ph Resistive Limit Zone 3 Resistive reach in secondary ohms for Zone 3 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 – 100 - 0.01 4 2-Ph Resistive Limit Zone 3 Resistive reach in secondary ohms for Zone 3 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 3 ground timer Zone 3 ground elements time delay 0 - 300 s 0.01 0.8 Zone 3 phase timer Zone 3 phase elements time delay 0 - 300 s 0.01 0.8 Zone 4 Enable Enable operation of Zone 4 distance No – Yes - 1 Yes Zone 4 direction Zone 4 measuring direction, forward or reverse. Note that when the pilot logic “Directional Comparison Blocking’, “Weak Infeed” and/or ‘Transient Block” is used, Zone 4 is always reverse, regardless of this setting.



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Description Range Units Step Actual Gnd. Distance Char. Selection of mho, reactance (quadrilateral), mho AND reactance, mho OR reactance for the ground distance elements. Note that the setting ‘Mho AND reactance’ requires both characteristics to operate for a trip to be produced. ‘Mho OR reactance’ produces a trip from either element. For applications when a larger resistive reach as compared to the reactive reach is required, the setting ‘Reactance’ or ‘Reactance OR Mho’ should be used.


Phase Distance Char. Selection of mho, reactance (quadrilateral), reactance AND mho, reactance OR mho the phase distance elements.


Characteristic Angle Characteristic line angle in degrees for the directional element for the quadrilateral characteristic. It is typically set at 75 degrees. See Description of Operation for definition of this angle. 0 - 90 deg 1 75 Lagging phase for PH-PH-G faults For two-phase-to-ground faults, the leading phase-ground element may overreach and is not allowed to measure. The lagging phase can be allowed to operate as it will underreach and is enabled by this setting. Two phase to ground faults will generally by detected by phase-phase elements, but in case high resistance is expected for these type of faults, the setting should be YES. No - Yes - 1 No Distance Block Timer When a digital input is used for blocking the distance protection, this timer provides drop-out delay of the block signal. Not used in factory default logic. 0 - 1000 ms 50 150 Duration memory This setting determines the polarization voltage memory duration, in cycles. Recommended setting is 2 cycles. 2 - 80 Cycles 1 2 Voltage Threshold Voltage threshold for the memory polarization. When the measured voltage is below the set threshold, memory is used. 0.1 – 5 V 0.1 1

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8.1.8 ZONE SUPERVISION SETTINGS – CURRENT ELEMENTS - MISC. CURRENT ELEMENTS

The distance relay zone elements are supervised by current elements, individually settable for single-phase-to-ground faults and phase-phase/three-phase faults. Typically, these elements are set above maximum load current but a lower setting can be applied for the ground measurement in case of high resistance ground faults for the application. Maximum load current for this application was given as 4.45 A secondary. Applying a 20% margin, the suggested setting is 5.34 A. Fault current studies should confirm this setting, taking into account the scheme used (stepped distance or pilot) and whether directional ground elements are applied to cover high resistance ground faults.

Description Range Units Step Actual 46 Open phase enable Enables the Broken Conductor (open phase) function No - Yes - 1 No 46 Open phase pick up Pick-up setting for broken conductor function. The pick-up level is set as I2/I1, the ratio of negative sequence and positive sequence current. 0.05 - 0.4 I2/I1 0.01 0.05 46 Open phase time delay Time delay for trip for broken conductor 0.05 - 300 s 0.01 0.05 46 Minimum load Sets minimum load level for the broken conductor function. If the positive sequence current is below this level, the broken conductor function is blocked. 0.10 - 5 A 0.01 0.5 Forward Sup. 1-Ph Minimum operating current for forward phase- ground impedance zone operation 0.20 - 7.5 A 0.01 5.34 Forward Sup. 2-Ph Minimum operating current for forward phase- phase and three-phase impedance zone operation 0.20 - 7.5 A 0.01 5.34 Reverse Sup. 1-Ph Minimum operating current for reverse phase-ground impedance zone operation. When using Zone 4 reverse looking for directional comparison blocking (DCB) pilot schemes, the reverse sensitivity should be set higher (lower setting of the current supervision element) than the forward elements to ensure proper coordination. 0.20 - 7.5 A 0.01 5.34 Reverse Sup. 2-Ph Minimum operating current for forward phase-phase and three-phase impedance zone operation. When using Zone 4 reverse looking for directional comparison blocking (DCB) pilot schemes, the reverse sensitivity should be set higher (lower setting of the current supervision element) than the forward elements to ensure proper coordination. 0.20 - 7.5 A 0.01 5.34 49 Thermal Img. Enable Enables the thermal image function No - Yes - 1 No

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Description Range Units Step Actual 49 Heating constant Heating constant for the line. 0.50 - 300 min 0.01 0.50 49 Cooling constant Cooling constant for the line. 0.50 - 300 min 0.01 0.50 49 Max. Sust. Curr. Maximum allowed continuous load current on the line 1 - 12.5 A 0.5 5 49 Alarm Level Thermal image alarm level 50 - 100 % 1 50 49 Thermal Memory If thermal memory is set to Yes, the function retains the last calculated thermal level in memory and uses this as start level when the GARD 8000 is put back into service. No - Yes - 1 No 49 Reset Threshold Thermal image reset level in % of alarm level. 50 - 100 % 1 80

8.2 GARD 8000 21L SETTING EXAMPLES – DIRECTIONAL COMPARISON BLOCKING

8.2.1 LINE The same example as for Stepped Distance protection is used. Nominal voltage 230 kV Nominal current 5 A Frequency 60 Hz Line length 54 miles Positive sequence Z1L Line impedance (primary ohms) 41.33@85 degrees Zero sequence Z0L Line impedance (primary ohms) 145.48@74 degrees Local source impedance Z1SL, positive sequence (primary ohms) 50@86 degrees Local source impedance Z0SL, zero sequence (primary ohms) 50@86 degrees Remote source impedance Z1SR, positive sequence (primary ohms) 50@86 degrees Remote source impedance Z0Sr, zero sequence (primary ohms) 50@86 degrees PT ratio 230 kV:115V = 2000 CT ratio 1000:5 = 200 Maximum load current (primary A) 890

8.2.2 CONVERSION TO SECONDARY VALUES According to the Stepped Distance example

8.2.3 CCVT SETTING According to the Stepped Distance example.

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8.2.4 GENERAL SETTINGS According to the Stepped Distance example.

8.2.5 LINE PROTECTION SYSTEM SETTINGS A typical DCB scheme uses three zones; Zone 1 as an independent underreach element, Zone 2 as a forward pilot zone and Zone 4 as a reverse carrier start zone. In the example below, only Zone 1 is enabled as an independent zone. Zone 2 and Zone 4 are only used for the pilot scheme and consequently disabled in the Trip Mask below. Zone 3 is also not used in this example. Note that Zone 2 or Zone 3 can be selected as the pilot zone. This example is using Zone 2. Zone 3 may be used as an independent time delayed backup zone for remote breaker failure. Zone 2 may also be used as a time delayed backup zone but as the setting should be made for pilot operation it may not provide the required selectivity as a backup element.

8.2.5.1 TRIP MASK VERSUS ELEMENT ENABLE Most functions have two enable settings. One in the Line Protection System Settings, which is the Trip Mask. Another on the corresponding element setting page, which is the element enable setting. For example, the Zone 2 element setting is on the page for “Distance Protection” “Zone 1 to 4.” The below figure explains the difference between the Trip Mask and Element enable settings. The figure is uses the example of Zone 2. The Zone 2 element can have two functions; independent trip after set Zone 2 time delay, and/or pilot operation through the selected pilot logic. The element itself (Zone 2 Enable on the Zone 1 to 4 page) needs to be enabled for either of these functions to operate. However, the Line Protection System Settings “Ground unit Z2” and “Phase unit Z2” can be disabled, and pilot operation will still take place. Only if time-delayed independent Zone 2 trip is desired, should the Distance Protection System settings be enabled.

Distance protection trip

Zone 2 Phase

Zone 2 Ground

Phase Units Z 2

Enable

Ground Units Z 2

Line Protection System Settings

Distance ElementsZone 1 to Zone 4

Zone 2 Enable

Pilot Logic

Enable

Enable

Zone 2 phase timer

Zone 2 ground timer

Yes

Yes

Yes

Figure 8-2. Trip Mask Enable and Element Enable (Directional Comparison Blocking)

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Note that in the “Line Protection System Settings” below, only settings related to DCB distance operation have been entered and enabled, which in this example means that only Zone 1 is set enabled.

Description Range Units Step Actual Line Pos.Seq. Impedance Magnitude Positive sequence impedance magnitude for the protected line in secondary ohms 0.01 - 100 Ohm 0.01 4.13 Line Pos.Seq. Impedance Angle Positive sequence impedance angle for the protected line in degrees 5 - 90 deg 1 85 Pos. Seq. Angle Zone 2 Positive sequence impedance angle for the protected line sections for Zone 2 in degrees 5 - 90 deg 1 85 Pos. Seq. Angle Zone 3 Positive sequence impedance angle for the protected line sections for Zone 3 in degrees 5 - 90 deg 1 85 Pos. Seq. Angle Zone 4 Positive sequence impedance angle for the protected line sections for Zone 4 in degrees 5 - 90 deg 1 85 Zone 1 k0 Factor Zero sequence compensation factor magnitude for Zone 1. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 3.52 Line Zero Seq. Impedance Angle Zero sequence impedance angle for the protected line in degrees 5 - 90 deg 1 74 Zone 2 k0 Factor Zero sequence compensation factor magnitude for Zone 2. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 3.52 Zone 2 Zero Seq. Angle Zero sequence impedance (Z0) angle in degrees for Zone 2. 5 - 90 deg 1 74 Zone 3 k0 Factor Zero sequence compensation factor magnitude for Zone 3. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 3.52 Zone 3 Zero Seq. Angle Zero sequence impedance (Z0) angle in degrees for Zone 3. 5 - 90 deg 1 74 Zone 4 k0 Factor Zero sequence compensation factor magnitude for Zone 4. k0=Z0/Z1 (unitless) 0.5 - 10 - 0.01 3.52 Zone 4 Zero Seq. Angle Zero sequence impedance (Z0) angle in degrees for Zone 4. 5 - 90 deg 1 74 Local Pos.Seq. Source Impedance Magnitude Positive sequence impedance magnitude for the local source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 5.00 Local Pos.Seq. Source Impedance Angle Positive sequence impedance angle for the local source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 85

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Description Range Units Step Actual Local Zero Seq. Source Impedance Magnitude Zero sequence impedance magnitude for the local source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 5.00 Local Zero Seq. Source Impedance Angle Zero sequence impedance angle for the local source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 85 Remote Pos.Seq. Source Impedance Magnitude Positive sequence impedance magnitude for the remote source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 5.00 Remote Pos.Seq. Source Impedance Angle Positive sequence impedance angle for the remote source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 85 Remote Zero Seq. Source Impedance Magnitude Zero sequence impedance magnitude for the remote source, in secondary ohms. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 0.01 - 100 Ohm 0.01 5.00 Remote Zero Seq. Source Impedance Angle Zero sequence impedance angle for the remote source, in degrees. Used for the fault locator. As the source impedance value may differ depending on system configuration, use the typical value. 5 - 90 deg 1 85 Parallel Line Pos.Seq. Magnitude Positive sequence impedance magnitude for a parallel line in secondary ohms. Used for mutual compensation for the fault locator.

0.01 - 10000 Ohm 0.01 1.25

Parallel Line Pos. Seq, Angle Positive sequence impedance angle for a parallel line in degrees. Used for mutual compensation for the fault locator. 5 - 90 deg 1 75 Parallel Line Zero Seq. Magnitude Zero sequence impedance magnitude for a parallel line in secondary ohms. Used for mutual compensation for the fault locator.

0.01 - 10000 Ohm 0.01 1.25

Parallel Line Zero Seq. Angle Zero sequence impedance angle for a parallel line in degrees. Used for mutual compensation for the fault locator. 5 - 90 deg 1 75 Fault Locator Units Determines display of fault locator calculation in % (% of Length) or in kilometers/miles (Length Units) as set for the parameter ‘Length Units’.

Length Units % of Length - 1 % of Length

Line Length Total line length in kilometers or miles, as set for the parameter ‘Length Units’. 0 - 400 - 0.01 100

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Description Range Units Step Actual Indication Zone Determines if fault location should be calculated and displayed for faults on the protected line only (In) or for all faults that are detected by the distance relay (In & Out)


Length Units Determines display of fault locator calculation in kilometers or miles, when parameter ‘Fault Locator Units’ is set to ‘Length Units’.

Kilometers Miles - 1 Miles

Mutual Coupl. Factor Mutual coupling factor to a parallel line for mutual compensation of the fault locator. The coupling factor is determined as |Z0/Zm0| 0 - 10 Ohm 0.01 0 Mutual Coupl. Angle Mutual coupling angle to a parallel line for mutual compensation of the fault locator. The angle is determined as LZ0 - LZm0 5 - 90 deg 1 25 Mut Coupl. Comp. Enable Turns mutual coupling compensation ON or OFF. For mutual coupling, the neutral ct current from the parallel line needs to be wired into the GARD 8000 relay. No - Yes - 1 No Pick Up Report This setting determines whether fault records should be triggered from pick-up of any element (YES) or following a trip only (NO). No - Yes - 1 Yes Three-Phase Trip Selects 3-pole tripping (Yes) or single pole tripping (No) No – Yes - 1 Yes 1 Pole Trip 67G Selects 3-pole tripping (No) or single pole tripping (Yes) from the directional ground element No – Yes - 1 No Ground Units Z1 Enables trip operation by Zone 1 ground distance units
















Remote Breaker Open Enables the remote open breaker logic.




Stub Bus Prot. Enables the stub bus protection logic.


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Description Range Units Step Actual Thermal Image Enables the thermal image element.


Open Phase Detector Enables open phase/broken conductor detector logic.


Pole Discrepancy Enables the pole discrepancy logic.


Out of Step Trip Enables out of step trip operation.






































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Description Range Units Step Actual 59-1 Enables trip by Phase Overvoltage, step 1.


































8.2.6 REACH SETTINGS The following is an example of a basic Directional Comparison Scheme with Z1 set to 80% of line impedance, Z2 set to 120%, Z3 not used and Z4 set to 50% in the reverse direction. The pilot zone reaches (Z2 forward and Z4 reverse) need to be coordinated with the settings of the remote relay, and take the line length into consideration. Short lines may need a larger margin, i.e. Z2 = 150% and Zone 4 = 200%. The increased margin for Zone 2 will ensure high speed pilot operation for all types of faults on the line. The increased margin for Zone 4 will ensure high speed blocking of the remote end for faults behind the local terminal.

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Short lines are defined by the IEEE Line Protection Guide (PC37.113) as lines with SIR > 4. SIR for the line in the example is:

SIR = 5Z1SL0.8 .Z1L

= 0.8 4.13. = 1.5 < 4

As this is not a short line, extended margins are not required and the zone settings 80%, 120%, 50% are consequently used in this example. Zone 1 reach 80% of ZL1 = 0.8 · 4.13 = 3.30 Time delay = 0 Zone 2 reach (forward pilot zone) 120% of ZL1 = 1.2 · 4.13 = 4.96 Zone 4 reach (reverse pilot zone) 50% of ZL1 = 0.5 · 4.13 = 2.07

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8.2.7 DISTANCE ELEMENTS – ZONE 1 TO ZONE 4 SETTINGS Description Range Units Step Actual Zone 1 Enable Enable operation of Zone 1 distance No – Yes - 1 Yes Zone 1 direction Zone 1 measuring direction, forward or reverse.


Zone 1 reach Zone 1 reactive reach in secondary ohms, at set characteristic line angle. 0.01 - 100 Ohm 0.01 3.30 1-Ph Resistive Limit Zone 1 Resistive reach in secondary ohms for Zone 1 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 – 100 - 0.01 4 2-Ph Resistive Limit Zone 1 Resistive reach in secondary ohms for Zone 1 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 1 ground timer Zone 1 ground elements time delay 0 - 300 s 0.01 0 Zone 1 phase timer Zone 1 phase elements time delay 0 - 300 s 0.01 0 Zone 1 quad tilt time delay Time delay for the load compensation of the reactive quadrilateral line. After this time, the load compensation is turned off and the line reverts to being parallel with the R-axis. Recommended time delay is 0.08 s (80 ms). 0 - 0.5 s 0.01 0 Zone 2 Enable Enable operation of Zone 2 distance No – Yes - 1 Yes Zone 2 direction Zone 2 measuring direction, forward or reverse.



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Description Range Units Step Actual Zone 3 Enable Enable operation of Zone 3 distance No – Yes - 1 No Zone 3 direction Zone 3 measuring direction, forward or reverse.


Zone 3 reach Zone 3 reactive reach in secondary ohms, at set characteristic line angle. 0.01 – 100 Ohm 0.01 8.26 1-Ph Resistive Limit Zone 3 Resistive reach in secondary ohms for Zone 3 phase-ground quadrilateral characteristic. Note that the set resistance is the direct loop resistance, without zero sequence compensation factor applied. For phase A, the resistance at the R-axis is Rset = VA/IA. 0.01 – 100 - 0.01 4 2-Ph Resistive Limit Zone 3 Resistive reach in secondary ohms for Zone 3 phase-phase quadrilateral characteristic. Note that the set resistance is the phase-phase resistance. For phase A to B, the resistance at the R-axis is Rset = VAB/IAB. 0.01 - 100 - 0.01 4 Zone 3 ground timer Zone 3 ground elements time delay 0 - 300 s 0.01 0.8 Zone 3 phase timer Zone 3 phase elements time delay 0 - 300 s 0.01 0.8 Zone 4 Enable Enable operation of Zone 4 distance No – Yes - 1 Yes Zone 4 direction Zone 4 measuring direction, forward or reverse. Note that when the pilot logic “Directional Comparison Blocking’, “Weak Infeed” and/or ‘Transient Block” is used, Zone 4 is always reverse, regardless of this setting.



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Description Range Units Step Actual Gnd. Distance Char. Selection of mho, reactance (quadrilateral), mho AND reactance, mho OR reactance for the ground distance elements. Note that the setting ‘Mho AND reactance’ requires both characteristics to operate for a trip to be produced. ‘Mho OR reactance’ produces a trip from either element. For applications when a larger resistive reach as compared to the reactive reach is required, the setting ‘Reactance’ or ‘Reactance OR Mho’ should be used.


Phase Distance Char. Selection of mho, reactance (quadrilateral), reactance AND mho, reactance OR mho the phase distance elements.


Characteristic Angle Characteristic line angle in degrees for the directional element for the quadrilateral characteristic. It is typically set at 75 degrees. See Description of Operation for definition of this angle. 0 - 90 deg 1 75 Lagging phase for PH-PH-G faults For two-phase-to-ground faults, the leading phase-ground element may overreach and is not allowed to measure. The lagging phase can be allowed to operate as it will underreach and is enabled by this setting. Two phase to ground faults will generally by detected by phase-phase elements, but in case high resistance is expected for these type of faults, the setting should be YES. No - Yes - 1 No Distance Block Timer When a digital input is used for blocking the distance protection, this timer provides drop-out delay of the block signal. Not used in factory default logic. 0 - 1000 ms 50 150 Duration memory This setting determines the polarization voltage memory duration, in cycles. Recommended setting is 2 cycles. 2 - 80 Cycles 1 2 Voltage Threshold Voltage threshold for the memory polarization. When the measured voltage is below the set threshold, memory is used. 0.1 – 5 V 0.1 1

8.2.8 ZONE SUPERVISION SETTINGS – CURRENT ELEMENTS - MISC. CURRENT ELEMENTS

The distance relay zone elements are supervised by current elements, individually settable for single-phase-to-ground faults and phase-phase/three-phase faults. Typically, these elements are set above maximum load current but a lower setting can be applied for the ground measurement in case of high resistance ground faults for the application. Maximum load current for this application was given as 4.45 A secondary. Applying a 20% margin, the suggested setting is 5.34 A, as determined for the Stepped Distance scheme. However, in order to further ensure that a reverse blocking element is more sensitive than the remote forward pilot zone, the reverse supervision elements (for Zone 4) are set more sensitive and a 10% margin is suggested instead of the 20%. The reverse elements are consequently set at 4.90 A for our example.

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Fault current studies should confirm this setting, taking into account the scheme used and whether directional ground elements are applied to cover high resistance ground faults.

Description Range Units Step Actual 46 Open phase enable Enables the Broken Conductor (open phase) function No - Yes - 1 No 46 Open phase pick up Pick-up setting for broken conductor function. The pick-up level is set as I2/I1, the ratio of negative sequence and positive sequence current. 0.05 - 0.4 I2/I1 0.01 0.05 46 Open phase time delay Time delay for trip for broken conductor 0.05 - 300 s 0.01 0.05 46 Minimum load Sets minimum load level for the broken conductor function. If the positive sequence current is below this level, the broken conductor function is blocked. 0.10 - 5 A 0.01 0.5 Forward Sup. 1-Ph Minimum operating current for forward phase- ground impedance zone operation 0.20 - 7.5 A 0.01 5.34 Forward Sup. 2-Ph Minimum operating current for forward phase- phase and three-phase impedance zone operation 0.20 - 7.5 A 0.01 5.34 Reverse Sup. 1-Ph Minimum operating current for reverse phase-ground impedance zone operation. When using Zone 4 reverse looking for directional comparison blocking (DCB) pilot schemes, the reverse sensitivity should be set higher (lower setting of the current supervision element) than the forward elements to ensure proper coordination. 0.20 - 7.5 A 0.01 4.90 Reverse Sup. 2-Ph Minimum operating current for forward phase-phase and three-phase impedance zone operation. When using Zone 4 reverse looking for directional comparison blocking (DCB) pilot schemes, the reverse sensitivity should be set higher (lower setting of the current supervision element) than the forward elements to ensure proper coordination. 0.20 - 7.5 A 0.01 4.90 49 Thermal Img. Enable Enables the thermal image function No - Yes - 1 No 49 Heating constant Heating constant for the line. 0.50 - 300 min 0.01 0.50 49 Cooling constant Cooling constant for the line. 0.50 - 300 min 0.01 0.50 49 Max. Sust. Curr. Maximum allowed continuous load current on the line 1 - 12.5 A 0.5 5 49 Alarm Level Thermal image alarm level 50 - 100 % 1 50

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Description Range Units Step Actual 49 Thermal Memory If thermal memory is set to Yes, the function retains the last calculated thermal level in memory and uses this as start level when the GARD 8000 is put back into service. No - Yes - 1 No 49 Reset Threshold Thermal image reset level in % of alarm level. 50 - 100 % 1 80

8.2.9 DISTANCE ELEMENTS – PILOT (COMMS SCHEME) SETTINGS The standard Directional Comparison Scheme uses a forward pilot zone (Z2 or Z3) and a reverse blocking zone (Z4). However, this scheme can be complemented with non-directional overcurrent start elements, Fast Carrier Start. Carrier start (blocking signal) is issued when the non-directional 50-P1 and 50-G1 (Fast carrier start) or when the reverse Z4 operates. The drop out of the Z4 signal is delayed by the time set on “Dist Coord Time.” Trip is issued when the forward pilot zone (Z2 or Z3) asserts, after the set pickup delay “DCB dist delay time.” AND no block signal (channel receive) is present. This indicates a forward fault, within set pilot zone reach. Carrier stop is issued when the forward pilot zone asserts, Z1 picks up or a pilot trip is issued. This indicates a forward fault.

8.2.9.1 FAST CARRIER START Fast Carrier Start is mainly used for one of two reasons:

1. Coordination with a remote E/M scheme that lacks channel coordination timer and has measuring elements of an “inverse” characteristic. The operating times of E/M distance relays are very dependent on settings (taps) and fault conditions while a microprocessor relay exhibits a more “flat” characteristic. In order to ensure that a block signal will be issued fast enough to block a remote E/M relay, non-directional overcurrent start is beneficial.

2. Shorter channel coordination time setting (DCB dist delay time). When Fast Carrier Start is used, the timer (DCB dist delay time) can be set to 0. This means that trip for internal faults will take place as soon as the forward pilot zone has detected the fault, without any additional delay.

Note that when Fast Carrier Start and 67 DCB are used, there are common elements and settings need to be coordinated. This coordination is covered in the last section in this document. If “Fast carrier start” is set to “NO,” the 50P-1 and 50G-1 elements are not used in the 21L DCB scheme. For the majority of applications, where the remote relay is of comparable design, Fast Carrier Start is not required. The most common way for DCB today is to have directional start (Z4) only.

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The Fast Carrier start involves two overcurrent settings; 50P-1 and 50G-1. These should be set so that they operate for any fault behind the relay that is within the forward pilot zone of the remote relay. (The elements are non-directional so they will also pick-up for a forward fault, but carrier will be stopped by the local forward pilot zone.) 50P-1 should be set above load current, and below the current supervision setting of the remote relay. Recommended setting is to use the same value as the current supervision (Reverse Sup. 2-Ph) applied to the reverse Z4; i.e. 4.90 A for this example. 50G-1 can be set more sensitive, as it does not operate on load current. A conservative setting would use the same value as the current supervision (Reverse Sup. 1-Ph) which in this example was 4.90 A. A more sensitive 50G-1 setting may be required when coordinating with a remote E/M scheme. As the operating time of E/M relays are very setting (tap) dependent, settings are typically determined by end-to-end testing.

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8.2.10 21L DCB TIMER SETTINGS There are two timer settings associated with DCB; Dist coord time and DCB dist delay time. Dist coord time extends the blocking signal (carrier start) from the reverse Z4 (note that the timer does not operate on the non-directional Fast carrier start as the latter will assert for forward faults as well). The recommended setting is 20 ms. DCB dist delay time is the time the forward pilot zone has to wait for a blocking signal before it is allowed to issue a trip. When using Fast carrier start, this timer can be set to 0, if extra high speed fault clearing is required. However, a more conservative setting of 10 ms is recommended. When not applying Fast Carrier start 10 ms is recommended. Note that these times assumed that the communication channel is a GARD ON/OFF carrier. Other carrier sets may have different drop-out characteristics that will have to be considered. In addition, a distance relay of different design at the remote end may warrant longer time delay settings.

Channel receive

Forward pilot zone

Out-of-step Block

Block pilot trip

Input channel stop

Zone 1 Fault

Enable OSB pilot

Distance pilot protection trip

Distance protection channel start

50P-1 Phase A

Reverse pilot zone (Z4)

50P-1 Phase B

50P-1 Phase C

50G-1 Ground

Fast carrier start

0

T

Dist Coord Time

Distance protection channel stop

T

0

DCB dist delay time

Figure 8-3. Directional Comparison Blocking (DCB) Distance Relay Scheme

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8.2.11 67 DCB SCHEME The 21L DCB Scheme can be complemented by a directional comparison blocking scheme for ground and/or negative sequence overcurrent. The directional ground DCB pilot logic uses directional ground and/or directional negative sequence elements. Both zero sequence and negative sequence elements can be used in the scheme, operating in parallel. However, it is recommended that the operator use either zero sequence or negative sequence, and not both. There are applications where zero sequence and negative sequence currents can have different directions for the same fault. This would defeat the DCB logic and misoperations may occur. Also make sure that the same elements are used at the two line ends. This setting example will use zero sequence elements only.

Channel receive

50 G-2

Trip 67 pilot

67 channel stop

50 G-1

0

T

67 Coord Time

67 channel start

T

0

DCB 67 delay time

Input block trip 67 pilot

50 Q-2

50 Q-1

50 G-3

50 Q-3

Input disable 67 pilot

67G reverse

67Q reverse

67G forward

67Q forward

Figure 8-4. Directional Comparison Blocking (DCB) Directional Overcurrent Scheme

Carrier start (blocking signal) is issued when the reverse 50G-3 (67G-3) and/or the reverse 50Q-3 (67Q-3) assert. The drop out of this signal is delayed by the time set on “67 Coord Time” Trip is issued when the forward 50G-2 (67G-2) and/or the forward 50Q-2 (67Q-2) assert, after the set pickup delay “DCB 67 delay time” AND no block signal (channel receive) is present. This indicates a forward fault, within set 67 pilot reach. Carrier stop is issued when the forward 50G-1 (67G-1) and/or the forward 50Q-1 (67Q-1) assert. This indicates a forward fault. Carrier stop is also issued by the forward 50G-2 (67G-2) and/or the forward 50Q-2 (67Q-2) elements, but not until the DCB 67 delay time has timed out.

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8.2.11.1 67 DCB SETTINGS 50G-1/50Q-1 (with their corresponding 67 forward directional supervision) are used as “underreach” elements for forward faults to provide a quick channel stop signal. The 50G-1/50Q-1 setting should be high enough to not pick up on zero sequence or negative sequence current produced by unequal breaker closing. A setting of 3 – 5 A is recommended. For this example, if Fast Carrier start were to be used, 50G-1 was set to 4.90 A for the 21L DCB, so the same value is used here. 50G-2/50Q-2 should be set to detect high resistive ground faults on the line. Typically, in a DCB scheme, it is sufficient if one line end detects the fault as the weak infeed end will trip sequentially after the stronger end has opened. 50G-2/50Q-2 (with their corresponding 67 forward directional supervision) should be set to 0.75% of minimum fault current for a ground fault on the line. Assuming minimum fault current to be 2 A, the 50G-2 setting used in this example is 1.5 A. 50G-3/50Q-3 (with their corresponding 67 reverse directional supervision) will block trip for a fault behind the local relay. Consequently, they should be set more sensitive than the remote 50G-2/50Q-2 elements. The recommended setting is 0.75% of 50G-2/50Q-2, which for this example results in 50G-3 = 1.12 A There are two timers associated with the 67 DCB scheme; 67 Coord Time and DCB 67 delay time. 67 coord time extends the blocking signal (carrier start) from the reverse 50G-3/50Q-3 element. The recommended setting is 20 ms. DCB 67 delay time is the time the forward 50G-2/50Q-2 element has to wait for a blocking signal before it is allowed to issue a trip. As high speed is not as critical for high resistive ground faults, a more conservative setting than for the 21L DCB is generally applied, e.g. 50 ms. Note that the Brkr Carrier sending setting is not applicable to a DCB scheme. Some DCB schemes use a 52b input to stop the carrier and the same function is available in the GARD System Logic. However, it enters the PLC directly and does not use the distance relay logic to perform this function. Hence, there is no setting associated with it in the distance relay; just input mapping required in the GARD “System Logic Configuration”.

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Description Range Units Step Actual Open Brkr Carrier sending Enables open breaker carrier send. Used with Permissive schemes (PUTT, POTT, DCUB, DTT). No - Yes - 1 No Security Time Sets a pick-up delay for a carrier receive signal for DTT schemes and weak feed logic. This will ensure that no spurious carrier signal will cause a false trip at the receiving end. 0 - 50 ms 1 0 Weak infeed Undervoltage Level Sets the undervoltage threshold for Weak Infeed tripping. 15 - 70 V 0.01 45 LOP Block Weak Infeed Enables block of weak infeed tripping by loss-of-potential block. No - Yes - 1 No Distance Pilot Scheme Selects the type of scheme used.

Step Distance Zone 1 Extension PUTT DTT POTT DCUB DCB - 1 DCB

Dist Carrier Time Sets the drop-out delay for carrier send. Used with Permissive schemes (PUTT, POTT, DCUB, DTT). 0 - 200 ms 10 50 Dist Coord Time Sets a coordination drop-out time delay for the carrier start signal from the reverse blocking zone, providing transient block function. 0 - 50 ms 1 20 DCB dist delay time Sets the time delay for Directional Comparison Blocking (DCB) trip signal. This is the amount of time the forward pilot zone will wait to receive a blocking carrier signal before trip is released. 0 - 200 ms 10 10 Z1 Ext. Block Time This is the time following breaker closing for when Zone 1 extension will become active. This prevents trip from an overreaching zone following reclosing. Used for Zone 1 Extension scheme. 0.05 - 300 s 0.01 10 Overreaching Zone Determines which zone is used as overreaching Pilot zone (Z2 or Z3).


Distance Weak Infeed Logic Output Set whether to use weak infeed echo (echo), week infeed trip and echo (ECHO+TRIP) or no weak infeed logic (None)


Enable Dist. Curr. Rev. trans. Blocking Enable Transient Block Logic for the overreaching permissive pilot schemes (POTT, DCUB) No - Yes - 1 No Carrier Fast Sending This setting is applicable to Directional Comparison Blocking (DCB) only and enables to select Carrier Start from non-directional phase and ground overcurrent elements, in addition to the reverse blocking zone. The 50P-1, 50G-1 elements are utilized for this function. No - Yes - 1 No

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Description Range Units Step Actual 67 Pilot Scheme Selects the type of pilot scheme to use for the directional overcurrent elements.

None PUTT DTT POTT DCUB DCB - 1 DCB

67 Carrier Time Sets the time delay for carrier send. Used with Permissive schemes (PUTT, POTT, DCUB, DTT). 0 - 200 ms 10 50 67 Coord Time Sets the coordination drop-out time delay for the carrier start signal. Used with Blocking schemes (DCB). 0 - 50 ms 1 20 DCB 67 delay time Sets the time delay for Directional Comparison Blocking (DCB) trip signal. This is the amount of time the forward overcurrent element zone will wait to receive a blocking carrier signal before trip is released. 0 - 200 ms 10 50 67 Weak Infeed Logic Output Set whether to use weak infeed echo (echo), week infeed trip and echo (ECHO+TRIP) or no weak infeed logic (None) for the overcurrent directional comparison pilot schemes.


Enable O/C curr. Rev. trans. blocking Enable Transient Block Logic for the overcurrent directional comparison pilot schemes. No - Yes - 1 No

8.2.12 21 DCB AND 67 DCB COORDINATION While the 50G-1 element is intended to detect “close-in” faults in the 67 DCB scheme, sensitivity required for 21 DCB has to take preference when using Fast carrier start. A more sensitive setting of this element will not defeat the 67 DCB scheme as this scheme is using the forward directional action (67G-1) of this element. If the application can produce zero sequence and negative sequence currents in opposite directions for an external fault, the settings need to be carefully reviewed when Fast carrier start is enabled:

1) Disable 50G-1. The remote forward directional ground will receive a block signal from the local reverse 50G-3 so use of the 50-G1 for the 21 DCB scheme is not necessary. (This is to prevent that 67-G1 will have an opposite direction of 67-Q1 and cause a legitimate block signal to drop out for an external fault.)

2) Use zero sequence only. Then the 50G-1 element should be set for the 21 DCB scheme.

If Fast carrier start is NOT used, no coordination is required and all 50 elements are set based on 67 DCB only.

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8.2.13 CURRENT ELEMENTS – PHASE ELEMENTS In this example, only 50-P1 for the Fast Carrier start is of interest for the application.

Description Range Units Step Actual Enable instantaneous phase (50P-1) Enable instantaneous phase overcurrent element, step 1 No - Yes - 1 Yes 50P-1 Pick-Up Pick-up level for instantaneous phase overcurrent element, step 1 0.05 - 150 A 0.01 4.90 50P-1 Time-Delay Time delay for instantaneous phase overcurrent element, step 1 0 - 300 s 0.01 0

50P-1 Torque Control Direction Directional control of instantaneous phase overcurrent element, step 1


50P-1 Torque Control Type Selection to use directional element or Zone 2 for torque control of the instantaneous phase overcurrent element, step 1

67P Z2 - 1 67P

Enable instantaneous phase (50P-2) Enable instantaneous phase overcurrent element, step 2 No - Yes - 1 No

50P-2 Pick-Up Pick-up level for instantaneous phase overcurrent element, step 2 0.05 - 150 A 0.01 5 50P-2 Time-Delay Time delay for instantaneous phase overcurrent element, step 2 0 - 300 s 0.01 0 50P-2 Torque Control Direction Directional control of instantaneous phase overcurrent element, step 2



67P Z2 - 1 67P

Enable instantaneous phase (50P-3) Enable instantaneous phase overcurrent element, step 3 No - Yes - 1 No 50P-3 Pick-Up Pick-up level for instantaneous phase overcurrent element, step 3 0.05 - 150 A 0.01 5

50P-3 Time-Delay Time delay for instantaneous phase overcurrent element, step 3 0 - 300 s 0.01 0 50P-3 Torque Control Direction Directional control of instantaneous phase overcurrent element, step 3



67P Z2 - 1 67P

Enable timeovercurrent phase (51P-1) Enable phase timeovercurrent element, step 1 No - Yes - 1 No

51P-1 Pick-Up Pick-up level for phase timeovercurrent element, step 1 0.10 - 125 A 0.01 2



Definite Time

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Description Range Units Step Actual 51P-1 Time Dial Set the time dial for the selected curve 0.05 - 10 - 0.01 1

51P-1 Time Delay Sets the minimum time delay for the curves with Time Limit (TL) for the phase timeovercurrent element, step 1 0.05 - 300 s 0.01 0.05

51P-1 Torque Control Direction Directional control of phase timeovercurrent element, step 1


51P-1 Torque Control Type Selection to use directional element or Zone 2 for torque control of the phase timeovercurrent element, step 1

67P Z2 - 1 67P

Enable timeovercurrent phase (51P-2) Enable phase timeovercurrent element, step 2 No - Yes - 1 No 51P-2 Pick-Up Pick-up level for phase timeovercurrent element, step 2 0.10 - 125 A 0.01 2



Definite Time

51P-2 Time Dial Set the time dial for the selected curve 0.05 - 10 - 0.01 1 51P-2 Time Delay Sets the minimum time delay for the curves with Time Limit (TL) for the phase timeovercurrent element, step 2 0.05 - 300 s 0.01 0.05




67P Z2 - 1 67P

Enable timeovercurrent phase (51P-3) Enable phase timeovercurrent element, step 3 No - Yes - 1 No

51P-3 Pick-Up Pick-up level for phase timeovercurrent element, step 3 0.10 - 125 A 0.01 2



Definite Time

51P-3 Time Dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1

51P-3 Time Delay Sets the minimum time delay for the curves with Time Limit (TL) for the phase timeovercurrent element, step 3 0.05 - 300 s 0.01 0.05




67P Z2 - 1 67P

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8.2.14 CURRENT ELEMENTS – GROUND ELEMENTS This example is using instantaneous ground elements for the Fast Carrier start (21L DCB) and the 67 DCB scheme. If negative sequence elements are selected for the 67 DCB, corresponding settings should be entered on “Current Elements – Negative Sequence Elements”. Note that Torque Control (Directional) is applied for the 67 DCB elements. However, the 50G-1 used in the Fast Carrier start logic is using the non-directional 50G-1 element.

Description Range Units Step Actual Enable instantaneous ground (50G-1) Enable instantaneous ground overcurrent element, step 1 No - Yes - 1 Yes 50G-1 Pick-Up Pick-up level for instantaneous ground overcurrent element, step 1 0.600 - 150 A 0.01 4.90 50G-1 Time-Delay Time delay for instantaneous ground overcurrent element, step 1 0 - 300 s 0.01 0 50G-1 Torque Control Direction Directional control of instantaneous ground overcurrent element, step 1

NO Forward Reverse - 1 Forward

50G-1 Torque Control Type Selection to use directional element or Zone 2 for torque control of the instantaneous ground overcurrent element, step 1

67G 67Q Z2G - 1 67G

Enable instantaneous ground (50G-2) Enable instantaneous ground overcurrent element, step 2 No - Yes - 1 Yes 50G-2 Pick-Up Pick-up level for instantaneous ground overcurrent element, step 2 0.600 - 150 A 0.01 1.50 50G-2 Time-Delay Time delay for instantaneous ground overcurrent element, step 2 0 - 300 s 0.01 0 50G-2 Torque Control Direction Directional control of instantaneous ground overcurrent element, step 2

NO Forward Reverse - 1 Forward


67G 67Q Z2G - 1 67G

Enable instantaneous ground (50G-3) Enable instantaneous ground overcurrent element, step 3 No - Yes - 1 Yes 50G-3 Pick-Up Pick-up level for instantaneous ground overcurrent element, step 3 0.600 - 150 A 0.01 1.12 50G-3 Time-Delay Time delay for instantaneous ground overcurrent element, step 3 0 - 300 s 0.01 0

50G-3 Torque Control Direction Directional control of instantaneous ground overcurrent element, step 3

NO Forward Reverse - 1 Reverse


67G 67Q Z2G - 1 67G

Enable timeovercurrent ground (51G-1) Enable ground timeovercurrent element, step 1 No - Yes - 1 No 51G-1 Pick-Up Pick-up level for ground timeovercurrent element, step 1 0.600 - 125 A 0.01 1

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Description Range Units Step Actual 51G-1 Time Curve Sets the time/current characteristic for ground timeovercurrent element, step 1


Definite Time

51G-1 Time Dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1 51G-1 Time Delay Sets the minimum time delay for the curves with Time Limit (TL) for the ground timeovercurrent element, step 1 0.05 - 300 A 0.01 0.05 51G-1 Torque Control Type Selection to use directional element or Zone 2 for torque control of the ground timeovercurrent element, step 1

67G 67Q Z2G - 1 67N

51G-1 Torque Control Direction Directional control of ground timeovercurrent element, step 1


Enable timeovercurrent ground 51G-2) Enable ground timeovercurrent element, step 2 No - Yes - 1 No

51G-2 Pick-Up Pick-up level for ground timeovercurrent element, step 2 0.600 - 125 A 0.01 1 51G-2 Time Curve Sets the time/current characteristic for ground timeovercurrent element, step 2


Definite Time

51G-2 Time Dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1

51G-2 Time Delay Sets the minimum time delay for the curves with Time Limit (TL) for the ground timeovercurrent element, step 2 0.05 - 300 s 0.01 0.05 51G-2 Torque Control Type Selection to use directional element or Zone 2 for torque control of the ground timeovercurrent element, step 2

67G 67Q Z2G - 1 67N



Enable timeovercurrent ground (51G-3) Enable ground timeovercurrent element, step 3 No - Yes - 1 No 51G-3 Pick-Up Pick-up level for ground timeovercurrent element, step 3 0.600 - 125 A 0.01 1

51G-3 Time Curve Sets the time/current characteristic for ground timeovercurrent element, step 3


Definite Time

51G-3 Time Dial Sets the time dial for the selected curve 0.05 - 10 - 0.01 1 51G-3 Time Delay Sets the minimum time delay for the curves with Time Limit (TL) for the ground timeovercurrent element, step 3 0.05 - 300 s 0.01 0.05

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Description Range Units Step Actual 51G-3 Torque Control Type Selection to use directional element or Zone 2 for torque control of the ground timeovercurrent element, step 3

67G 67Q Z2G - 1 67N



8.2.15 GROUND DIRECTIONAL SETTINGS The operation of the ground directional unit is based on zero sequence quantities. The operating quantity is the zero sequence current and the polarizing quantity is the zero sequence voltage. The operating quantity is I0. The polarizing quantity is –V0 + (I0 x set compensation factor)@ (ANG_67G). The compensation factor in the polarizing quantity formula is intended to increase the available polarizing quantity by boosting the magnitude, when required. The majority of applications has this factor set to 0. The minimum polarizing voltage (67G Minimum voltage) is settable 0.05 – 10 V. If the magnitudes are below the set threshold, the unit will not be able to make a directional determination and the overcurrent units are blocked or allowed to issue a non-directional trip as selected by the setting “Loss of polarization blocking.” With this set to “No” the elements are blocked. With this set to “Yes” the elements are allowed to trip non-directional. As the 67DCB scheme will be defeated without directional discrimination, the “Loss of polarization blocking” should be set to “Yes” in case there is a possibility of the polarization voltage dropping below the set threshold for the actual application. Recommended setting for Minimum voltage is 1 V and for Voltage Compensation 0. The 67G Characteristic angle should be set equal to the local zero sequence source impedance angle (Z0SL). In our example Z0SL = 86 degrees.

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8.2.16 CURRENT ELEMENTS – DIRECTIONAL ELEMENTS

Description Range Units Step Actual 67P Characteristic angle Characteristic angle for phase directional elements 0 - 90 deg 1 45 67G Characteristic angle Characteristic angle for ground directional elements 0 - 90 deg 1 86 Characteristic angle 67Q Characteristic angle for negative sequence directional elements 0 - 90 deg 1 45 67P Minimum voltage Minimum polarizing voltage threshold for phase directional elements 0.05 - 10 V 0.01 0.2 67G Minimum voltage Minimum polarizing voltage threshold for ground directional elements 0.05 - 10 V 0.01 1.00 67Q Minimum voltage Minimum polarizing voltage threshold for negative sequence directional elements 0.05 - 10 V 0.01 0.2

Resid. Volt. Compensation Sets a factor to amplify available zero sequence voltage polarization level 0 - 50 - 0.01 0 Negative Sequence Voltage Compensation Sets a factor to amplify available zero sequence voltage polarization level 0 - 50 - 0.01 0 Loss of polarization blocking Select whether to block overcurrent element when polarization voltage is below set thresholds (Yes) or to allow the elements to operate non-directional (No). No - Yes - 1 Yes Coordination time This is a timer setting for transient block logic when the directional overcurrent elements (50P and/or 50Q/G) are used in a permissive pilot scheme. 0 – 30 ms 1 0

In case negative sequence elements are used for the 67 DBC scheme, the same discussion applies but the Characteristic angle 67Q should be set equal to the local source negative sequence angle (which may be equal to the source positive sequence angle Z1SL, e.g. 86 degrees in our example).

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Description of Operation


SECTION 9. DESCRIPTION OF OPERATION

9.1 DISTANCE ELEMENTS The GARD 8000 Distance Protection Module is provided with four independent protection zones. The operating direction for each zone, forward or reverse, is selected using the ‘Zone n direction’ setting on web page Distance Elements, Zone1 to Zone4. The Zone 4 direction can be forced reverse, depending on what pilot scheme is selected. When the selected protection scheme is either Directional Comparison Blocking or when Weak Infeed Logic or Transient Block Logic is used, Zone 4 will operate as reverse-looking even if the setting is forward. Therefore, when either of these schemes is in use, it is not necessary to adjust the Zone 4 direction. Each zone has six measuring elements, one for each type of fault. The measuring element operates based on a phase angle comparison of an operate phasor and a polarization phasor. The two phasors are derived from the voltage and current phasors, and the specific settings for the zone. The ground fault elements use a compensation factor for the ground return in order to measure an impedance proportional to the line’s positive sequence impedance. This compensation factor is the setting K0, defined as: K0=ZL0/ZL1, where ZL0 and ZL1 are the zero sequence and positive sequence impedances of the line. Each zone has an individual reach setting (positive sequence impedance) and individual setting of the zero sequence compensation factor (K0=ZL0/ZL1), as well as individual phase angle setting. This enables a more exact setting for applications with mixed line properties, such as an overhead section followed by a cable section. Fault detection is made by use of mho and/or quadrilateral characteristic, with a setting for Quadrilateral characteristic, Mho characteristic, or both of them simultaneously, operating in an OR or AND logic. The reactive reach setting is common for both the Quadrilateral and Mho characteristics. Mho elements have a closed circular and directional characteristic, while the Quadrilateral elements have open non-directional characteristics. Hence, Quadrilateral elements are complemented with a directional unit and a resistive limiter with adjustable reach.

9.1.1 MHO CHARACTERISTIC The GARD 8000 Mho characteristic is polarized by the positive sequence voltage of the corresponding phase. This polarization gives the following characteristic, similar to cross-polarization:

• Variable: The Mho circle always includes the origin, and the diameter is a function of the source impedance.

• Dynamic: The Mho circle diameter varies from the inception of the fault to a return to the steady state.

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For faults with low positive sequence voltage (less than 10 V), memory voltage is used. The following table shows the operation and polarization phasors of the Mho characteristic measuring elements, as well as the applied operating criterion.

Table 9-1. MHO Characteristic

Unit OP POL Criteria AG [ 0( 0 1)]Ia I k ZF Va+ − ⋅ − Va1M BG [ 0( 0 1)]Ib I k ZF Vb+ − ⋅ − Vb1M CG [ 0( 0 1)]Ic I k ZF Vc+ − ⋅ − Vc1M AB Iab ZF Vab⋅ − Vab1M BC

90 [arg( ) arg( )] 90OP POL− ° ≤ − ≤ °

Ibc ZF Vbc⋅ − Vbc1M Ica ZF Vca⋅ − Vca1M CA

Table 9-2. MHO Characteristic Table Definitions

Figure 8-1 shows the phase-to-ground fault Mho characteristics. Due to the polarization used, the diameter of the characteristic is the vector addition of the adjusted reach and a vector corresponding to the local source impedance. This effect enables tripping for close in faults with very low voltage. This displacement has no effect on the directional characteristic. For a reverse fault, the mho characteristic is displaced in the forward direction.

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ZSL(Ieq-Ia1)

IeqZset

FIFRF

Va1

Figure 9-1. MHO Phase-Ground Characteristic (I)

Figure 9-1 shows a ground fault MHO characteristic at the inception of a fault. With the voltage memory feature, the positive sequence voltage two cycles prior to the fault is used to polarize the MHO characteristic. The diameter of the characteristic is increased by the impedance:

1( )LS eqZ I I⋅ − Figure 9-2 shows a ground fault Mho characteristic for a reverse fault. This characteristic demonstrates a displacement that is defined by the vector:

1( ) (L LS eq )Z Z I I+ ⋅ −

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IeqZset

Va1

Va

(ZL+ZRS)(Ieq-Ia1)

F

Figure 9-2. Mho Phase-Ground Characteristic (II) Where:

Table 9-3. MHO Phase-Ground Characteristic Definitions

ZLS Local source positive sequence impedance

ZL Line positive sequence impedance

ZRS Remote source positive sequence impedance

Zset Set reach

Ieq Equivalent ground fault current = Iphase + I0(K0-1)

Ia Phase A current. The same measurement is being made for phase B and C.

I1 Positive sequence fault current

Va Phase A voltage. The same measurement is being made for phase B and C.

V1 Polarizing voltage. Positive sequence voltage, referenced to the faulted phase.

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Figure 9-3 and Table 9-4 show the phase-to-phase fault Mho characteristics. These figures have been drawn for a forward fault current. In the case of a reverse fault current, the characteristic layout would be different, and the origin would be outside the characteristic as shown in Figure 9-2.

ZSL(Iph-ph-Iload)

Iph-phZset

FIFph-phRF/2

Vph-ph1M

Figure 9-3. Phase-Phase Mho Characteristic (I)

Figure 9-3 shows a characteristic at the instant of a fault. Using the voltage memory feature, the positive sequence voltage prior to the fault is used to polarize the characteristic. The characteristic diameter is increased by the impedance

( )LS loadZ I IΦΦ − When the buffer for the voltage memory has expired during a sustained fault, the source impedance vector becomes:

1( )LSZ I IΦΦ ΦΦ− where

Table 9-4. Phase-Phase Mho Characteristic Definitions

ZLS Local source positive sequence impedance

Iph-ph Phase to phase current (Iab, Ibc, Ica)

Iph-ph1 Positive sequence phase to phase current

Iload Phase to phase load current

Vph-ph Phase to phase voltage

Vph-ph1M Polarizing voltage. Positive sequence voltage for the corresponding phases, directly or from memory buffer

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9.1.2 QUADRILATERAL CHARACTERISTIC The GARD 8000 uses a load compensated Quadrilateral characteristic, polarized with the negative sequence current of the corresponding phase, eliminating over- and under-reach due to the remote-end infeed current’s effect on the fault impedance. This compensation is equivalent to a tilt in the characteristic, which is defined as tilt angle. This tilt angle is only applied during a short time after the fault occurs. This time is set with the parameter ‘Zone 1 quad tilt time delay’ on web page Distance Elements / Zone 1 to Zone 4. Once the timer expires, the characteristic returns to its original position. Load compensation is applied only to Zone 1 as the other zones are set overreaching with sufficient margin not to be affected by over- or under-reach. The following table shows the operation and polarization phasors of the Quadrilateral characteristic measuring elements, as well as the applied operation criteria.

Table 9-5. Quadrilateral Characteristics

Reactance Characteristic

Element Operate phasor (OP) Polarization Phasor (POL)

Criteria

AG ( )[ ] VaZnF1K0nI0Ia −⋅−⋅+ Ia2 or Ia-Iapf

BG ( )[ ] VbZnF1K0nI0Ib −⋅−⋅+ Ib2 or Ib-Ibpf

CG ( )[ ] VcZnF1K0nI0Ic −⋅−⋅+ Ic2 or Ic-Icpf ( ) ( )0º arg arg 180ºOP POL≤ − ≤⎡ ⎤⎣ ⎦

AB VabZnF −⋅Iab Iab-Iabpf

BC VbcZnF −⋅Ibc Ibc-Ibcpf

CA VcaZnF −⋅Ica

Ica-Icapf

Table 9-6. Quadrilateral Characteristics Definitions

Ia, Ib, Ic Phase currents Iapf, Ibpf, Icpf Pre-fault phase currents (load) Iab, Ibc, Ica Phase-phase currents (Ia-Ib), (Ib-Ic), (Ic-Ia) Iabpf, Ibcpf, Icapf Pre-fault phase-phase currents (Iapf-Ibpf), (Ibpf-Icpf), (Icpf-

Iapf) Ia2, Ib2, Ic2 Negative sequence currents, referenced to each phase I0 Zero sequence current Va, Vb, Vc Phase voltages Vab, Vbc, Vca Phase-phase voltages (Va-Vb), (Vb-Vc), (Vc-Va) Z1n Zone n set reach, (n=1,...,4) Z0n Zone n set reach for zero sequence impedance, (n=1,...,4)

Z1nZ0n

K0n =

Zero sequence compensation factor for zone n, (n=1,...,4)

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The ground fault reactance elements are normally polarized by negative sequence current which is parallel to the fault current through the fault resistance. However, the negative sequence current is not useful during a single pole open interval or for two-phase-to-ground faults. For these cases the negative sequence current is replaced by the faulted phase current less the pre-fault load current which will be in phase with the voltage drop over the fault resistance. Figure 9-4 and 9-5 show the Reactance characteristic, and the corresponding phasors. In Figure 9-4, the point F indicates where the fault occurs, and point F´ indicates where the relay measures the fault. As shown, the points do not coincide due to the IF RF vector, which represents the voltage drop in the fault impedance. Under no-load conditions, this vector would be horizontal, and F´ would be located on the horizontal line passing through F. Remote-end infeed creates a rotation by an angle α that displaces F´ to the point shown in the figure.

Figure 9-4. Reactance Characteristic (I)

When the characteristic C1 (representing no remote-end-in-feed conditions) is rotated by an angle alpha, the characteristic is changed, as shown by C2. Thus, F´ remains inside the operating zone. Rotation of the Reactance characteristic (polarized by negative sequence current) compensates for the voltage drop produced by the fault impedance (as seen by the relay), avoiding both overreach and underreach.

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Figure 9-5. Reactance Characteristic (II)

Figure 9-5 shows the Reactance characteristic under a no-load system (without remote-end current infeed to the fault). In this case, the fault is seen by the relay to be rotated by an angle gamma due to the lack of homogeneity on the system. The tilt angle changes the characteristic from C1 to C2, avoiding overreach of the relay during the preset tilt time, and allowing the adjacent protection elements to clear the fault. Angle gamma is calculated by the relay from the line and source impedances. IF Phase current Ieq Equivalent current: Ieq=IF+I0(k0-1)

Phase voltage VF RF Ground fault resistance IF Current through ground fault resistance Z1F Set reach

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9.1.3 DIRECTIONAL ELEMENT The directional unit consists of elements for each type of fault, common to the four zones. These elements are polarized by the positive sequence voltage (with memory when required) of the corresponding phase or phases.

Figure 9-6. Directional Unit

Assume a system with Ia2 in phase with Ieq. A directional characteristic C3 is then added to the Reactance characteristic C2. The following table shows the operate and polarization phasors of the directional elements, as well as the applied operating criteria.

Table 9-7. Directional Unit

Directional element

Unit OP POL Criteria AG Ia Va1 BG Ib Vb1 CG Ic Vc1 AB Iab Vab1M BC Ibc Vbc1M CA Ica Vca1M

( ) ( ) ( ) ( )90º arg arg 90ºOP POLα α− + ≤ − ≤ +⎡ ⎤⎣ ⎦

Where:

Table 9-8. Directional Unit Definitions

Ia, Ib, Ic Phase currents

Iab, Ibc, Ica Phase-phase currents (Ia-Ib), (Ib-Ic), (Ic-Ia) Va1, Vb1, Vc1 Positive sequence voltage, referenced to each phase Vab1M, Vbc1M, Vca1M Positive sequence memory (when applicable) voltage, phase-phase

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9.1.4 RESISTIVE BLINDER

Figure 9-7. Resistive Blinder

The GARD 8000 quadrilateral element is provided with six resistive limiters, one for ach type of fault, with independent reach settings for each zone. The reach of the resistive limiter for phase-to-ground and phase-to-phase faults are independent from each other. The characteristic is polarized by the equivalent current of the corresponding phase; hence, they are parallel to the reactance axis. Figure 9-7 shows the resistive limiter characteristic C4 and C5, added to the Reactance and Directional characteristics C2 and C3. Both C4 and C5 are at an angle to resistive axis equal to the positive sequence loop impedance for the zone in question. In the above figure, Ieq is the ground fault equivalent current:

The following table shows the operate and polarization phasors of the resistive limiters, as well as their operating criteria.

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Table 9-9. Resistive Limiter Characteristic

Resistive Limiter – Axis R>0 Characteristic Unit OP POL Criteria AG VaRGnIa −⋅ RGnIa ⋅

BG VbRGnIb −⋅ RGnIb ⋅

CG VcRGnIc −⋅ RGnIc ⋅ ( ) ( ) ( )90º OP POLθ θ⎡ ⎤− + ≤ ∠ −∠ ≤⎣ ⎦

Resistive Limiter – Axis R<0 Characteristic Unit OP POL Criteria AG VaRGnIa −⋅− RGnIa ⋅−

BG VbRGnIb −⋅− RGnIb ⋅−

CG VcRGnIc −⋅− RGnIc ⋅− ( ) ( ) ( )90º OP POLθ θ⎡ ⎤− − ≤ ∠ −∠ ≤⎣ ⎦

Resistive Limiter – Axis R>0 Characteristic Unit OP POL Criteria AB VabRPnIab −⋅ RPnIab ⋅

BC VbcRPnIbc −⋅ RPnIbc ⋅

CA VcaRPnIca −⋅ RPnIca ⋅ ( ) ( ) ( )90º OP POLθ θ⎡ ⎤− + ≤ ∠ −∠ ≤⎣ ⎦

Resistive Limiter – Axis R<0 Characteristic Unit OP POL Criteria AB VabRPnIab −⋅− RPnIab ⋅−

BC VbcRPnIbc −⋅− RPnIbc ⋅−

CA VcaRPnIca −⋅− RPnIca ⋅− ( ) ( ) ( )90º OP POLθ θ⎡ ⎤− + ≤ ∠ −∠ ≤⎣ ⎦

Where:

Table 9-10. Resistive Limiter Characteristic Definitions

Ia, Ib, Ic Phase currents Iab, Ibc, Ica Phase-to-phase currents (Ia-Ib), (Ib-Ic), (Ic-Ia) Va, Vb, Vc Phase voltages Vab, Vbc, Vca Phase-to-phase voltages RGn Resistive reach for ground faults corresponding to zone n RPn Resistive reach for phase-to-phase faults corresponding to zone n

nθ Positive sequence reach impedance angle corresponding to zone n bθ Loop impedance angle for zone n:

[ ]( ) ( )b n Ia Ieqnθ θ= − ∠ −∠

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9.1.5 DISTANCE CHARACTERISTIC The Mho and Quadrilateral characteristics can be used independently, or combined. There are four setting choices available; Mho only, Quadrilateral only, Mho AND Quadrilateral, and Mho OR Quadrilateral. These selections are done independently for phase-to-ground elements and phase-to-phase elements but are common to all zones.

9.1.6 DISTANCE ELEMENTS OPERATIONAL LOGIC The distance elements AG, BG, CG, AB, BC and CA for Zone to Zone 4 are combined with a number of other supervisory elements to produce an output:

• Current supervision elements • Phase selector • Open pole detector • Fuse fail (loss-of-potential) detector • Load encroachment

Phase to ground fault element logic is shown in the Figure below. Single-phase to ground measuring elements in the leading phase are not allowed to operate for two-phase to ground faults as they will overreach. However, the lagging phase can be allowed to operate as it will be underreaching. This is enabled by the setting “Lagging phase for PH-PH-G faults”. In either case, two-phase-to-ground faults will also be measured by the phase-to-phase impedance unit. The ‘pole-open’ release of the single phase to ground element is used for single pole trip applications when the phase selector is not operational during the open pole interval.

ZONE n AG (C_n_AG) DISTANCE CHARACTERISTIC

FORWARD AG ELEMENTS SUPERVISION (IDA)

AG FAULT (AG)

CAG FAULT (CAG)

PHASE LAG ENABLE SETTING

ZONE n (n_AG) AG ELEMENT PICKUP

POLE B OPEN (PB_A)

POLE C OPEN (PC_A)

FUSE FAILURE BLOCKING (BLQ_FF)

LOAD ENCROACHMENT ACTIVATION (DEL)

Figure 9-8. AG Distance Element Operational Logic

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The operational logic for a two-phase element is shown in the figure below.

Figure 9-9. AB Distance Element Operational Logic

9.1.7 MEMORY VOLTAGE LOGIC Memory voltage is only used for close-in three phase faults when the positive sequence voltage is less that the set threshold (0.2 – 5.0 V). In addition, if the series compensated setting is used, memory voltage is always used for three phase faults due to the possibility of voltage reversals for those applications. The positive sequence voltage memory buffer stores the voltage from two cycles before fault inception, as determined by a fault detector. The use of memory voltage is conditional; in addition, the memorized positive sequence voltage is only used if its value is above 20 V to prevent use of memory for close-into-fault conditions with 0 pre-fault voltage. The duration of using memory voltage is determined by the setting ‘Duration Memory’ on web page Zone 1 to Zone 4. The memory duration is generally set relatively short, typically 4 cycles. Only if time-delayed Zone 2 operation for faults with terminal voltage below the set threshold is required would the memory duration need to be extended to last for set Zone 2 time delay.

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9.1.8 SUPERVISION ELEMENTS The distance relay contains overcurrent elements to supervise the operation of the distance measuring elements. These overcurrent elements are used to establish a minimum current level of operation for the distance elements. Supervision elements are divided into two groups:

• Forward supervision • Reverse supervision

Each includes supervision of phase currents and line currents. Forward and reverse supervision elements are non-directional overcurrent elements. The following table lists supervision elements with their operation current and pickup settings. The output signal generated is also included.

Table 9-11. Supervision Elements Direction Element Iop Pickup Setting Output

Phase A Ia Forward AG elements supervision

Phase B Ib Forward BG elements supervision

Phase C Ic

Single-Phase Forward

Forward CG elements supervision

Phases AB Iab Forward AB elements supervision

Phases BC Ibc Forward BC elements supervision

Forward

Phases CA Ica

Two Phases Forward

Forward CA elements supervision

Phase A Ia Reverse AG elements supervision

Phase B Ib Reverse BG elements supervision

Phase C Ic

Single-Phase Reverse

Reverse CG elements supervision

Phases AB Iab Reverse AB elements supervision

Phases BC Ibc Reverse BC elements supervision

Reverse

Phases CA Ica

Two Phases Reverse

Reverse CA elements supervision

where

Table 9-12. Supervision Elements Definitions

The forward or reverse supervision element will pick up when the true RMS value of the corresponding phase or line current exceeds 105% of the pickup value, and resets below the pre-set value. Note that the supervision elements’ settings reside on the web page for “Misc. Current Elements” under the main heading “Current Elements”.

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9.2 NON-PILOT AND PILOT SCHEMES

9.2.1 STEPPED DISTANCE The stepped distance logic is always active. The Stepped Distance protection scheme can be selected alone or as a complement to any of the other schemes. Operation of the Stepped Distance scheme is based on the time delay of the different zones; therefore, communication is not required.

Phase A Zone n Unit

Phase B Zone n Unit

Phase C Zone n Unit

Phase AB Zone n Unit

Phase BC Zone n Unit

Phase CA Zone n Unit

0

30 ms

ZnGdelay

0

ZnPdelay

0Zn Ph PU/Zone n Phase Units Pick Up

Zn G PU/Zone n Ground Units Pick Up

Enable ZnG

Enable ZnP

Zone n Fault

Figure 9-10. Zone Logic

Ser comp block (option)

Out-of-step Block

Enable Z1 OSB

Enable Z2 OSB

Enable Z3 OSB

Enable Z4 OSB

Zone 1StepDistance

Zone 2StepDistance

Zone 3StepDistance

Zone 4StepDistance

LOP Block Trip

Step Distance

Zone 1 Fault

Zone 2 Fault

Zone 3 Fault

Zone 4 Fault

Figure 9-11. Stepped Distance Logic

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The stepped distance logic generates the Pickup signals of the phase and ground elements for zones 1, 2, 3, and 4, using the Mho and Quadrilateral elements outputs. Once the Phase Time Delay and Ground Time Delay settings have been adjusted for each zone, the elements will be ready for a trip operation. Activation of a zone element can be blocked for power swing conditions. This is achieved when the corresponding Power swing Element Blocking setting are set to (YES). If this value is set to (NO), the zone elements will activate independently of the Power swing detector status. Step distance tripping can also be blocked in case of a loss-of-potential condition. To select this feature, the LOP Loss-of-Potential Blocking must be enabled. LOP may be detected by the terminal unit itself or externally detected through the VT Fuse Failure status contact input.

9.2.2 ZONE 1 EXTENSION Zone 1 extension is a non-pilot scheme where fast fault clearing for 100% of the line is accomplished without a communications channel in conjunction with the recloser operation. This scheme provides fast tripping of the overreaching zone (set beyond 100% of the line length). As this scheme can make the relay operate for faults on the adjacent line, Zone 1 extension is inhibited following reclose to avoid a second trip for an external permanent fault. The blocking time ‘Z1 extension block time’ should be set longer than the dead-time reclose interval. If selected by setting, the Zone 1 Extension is blocked by a power swing.

Any pole open

Power swing block

Forward pilot zone

Enable Power swing block

Distance pilotprotection trip

0

T

Z1 extension blocktime

Figure 9-12. Zone 1 Extension

9.2.3 PERMISSIVE UNDERREACH TRANSFER TRIP (PUTT) The PUTT sends a permissive trip signal for faults on the line only. The receiving end is then allowed to trip provided that its forward overreaching zone has detected a fault. The purpose of the scheme is to speed-up tripping for end zone faults that is outside zone 1 reach from one line end. The security provided by the PUTT scheme may be advantageous on parallel line applications as transient block logic is not required. It should be confirmed however that the two zone 1 elements cover the center of the line for all possible faults, considering that the reach might have been reduced due to mutual coupling effects.

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STATION “A” Z2

STATION “B” Z2

BKRA

BKRB

+

T2A

“A” Z2

RXA

TRIP BKR A

“A” Z1

TRANSMITTRIP B

+

T2B

“B” Z2

RXB

TRIP BKR B

“B” Z1

TRANSMITTRIP A

STATION “A” Z1

STATION “B” Z1

STATION “A” Z2

STATION “B” Z2

BKRA

BKRB

+

T2A

“A” Z2

RXA

TRIP BKR A

“A” Z1

TRANSMITTRIP B

+

T2B

“B” Z2

RXB

TRIP BKR B

“B” Z1

TRANSMITTRIP A

STATION “A” Z1

STATION “B” Z1

Figure 9-13. Permissive Underreach Transfer Trip (PUTT) Permissive Underreach is activated when selected in the Protection Scheme setting. It functions as a complement to the Step Distance scheme. With this scheme, if a terminal locates the fault inside zone 1 (adjusted below 100% of the line), and the other terminal locates the fault inside zone 2 (adjusted over 100% of the line), the fault is considered internal to the transmission line; closer to the terminal that initially detects the fault. The terminal detecting the fault inside zone 1 will generate an instantaneous tripping signal and transmit this channel signal to the remote end to allow tripping. If any overreach measuring element (zone 2 or zone 3) has picked up, the remote terminal will trip instantaneously when the channel signal is received.

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Carrier Receive

Forward pilot zone

Three Poles Open

Power swing block

Block pilot trip

Weak infeed tripdistance

Zone 1 Fault

100ms

0 Enable open breakercarrier send

0

T

Dist carrier sendextend time

Enable Distancepilot scheme

power swing block


Distanceprotection channel

start

Figure 9-14. PUTT

An open circuit breaker carrier send signal selection is included in the settings, ‘Enable open breaker carrier send’. To determine if the three poles have opened, three status contact inputs (one for each pole) can be used, or one input can be used that corresponds to the three poles in series. The “Dist carrier send extend time’ provides a minimum time for channel signal transmission. Channel tripping and channel sending can be disabled using the status contact input ‘Block pilot trip’. It can also be disabled for power swing conditions by adjusting the Power swing Element ‘Distance pilot scheme power swing block’ setting. In case weak infeed logic is to be used with the PUTT scheme, the setting should be ‘TRIP+ECHO’. The ‘Echo’ setting is of no use for an underreach scheme and the ‘Trip+ECHO’ setting allows for local trip, even though no echo function will be performed (as the sending end has already tripped from its sending, underreach zone).

9.2.4 DIRECT TRANSFER TRIP This scheme is similar to Permissive Underreach Transfer Trip (PUTT) with the difference that channel signal reception produces instantaneous tripping without additional supervision. The carrier receive signal is provided with a pick-up delay to prevent tripping for spurious carrier signals, set on timer ‘Security Time’. Carrier send (Distance protection channel start) can be initiated by an open breaker as selected by the setting ‘Enable open breaker carrier send’. Power swing can be set to block carrier send by the setting ‘Distance pilot scheme power swing block’ and both trip and carrier send are blocked by the signal input ‘Block pilot trip’.

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Carrier Receive

Three Poles Open

Power swing block

Block pilot trip

Zone 1 Fault

100ms


Enable Distancepilot power swing block

Distance pilot protectiontrip

Distance protectionchannel start

0

T


T

0

Security Time

Figure 9-15. Direct Transfer Trip (DTT)

9.2.5 PERMISSIVE OVERREACH (POTT)

STATION “A” Z2

STATION “B” Z2

BKRA

BKRB

TRIP BKR A

+

T2A

“A” Z2

TRANSMITTRIP B

RXA

TRIP BKR B

+

T2B

“B” Z2

TRANSMITTRIP A

RXB

STATION “A” Z2

STATION “B” Z2

BKRA

BKRB

TRIP BKR A

+

T2A

“A” Z2

TRANSMITTRIP B

RXA

TRIP BKR A

+

T2A

“A” Z2

TRANSMITTRIP B

RXA

TRIP BKR B

+

T2B

“B” Z2

TRANSMITTRIP A

RXB

TRIP BKR B

+

T2B

“B” Z2

TRANSMITTRIP A

RXB

Figure 9-16. Permissive Overreach Transfer Trip (POTT) Permissive Overreach is activated when selected in the Pilot Scheme setting. It will function as a complement to the Step Distance scheme. In this scheme, assume one terminal locates the fault inside zone 1 (adjusted below 100% of the line) or inside zone 2 (adjusted over 100% of the line, overreaching). The other terminal locates the fault inside zone 2 (adjusted over 100% of the line, over-reaching). The fault would be considered internal to the transmission line between the terminals, closer

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to the second terminal with the remote end detecting the fault only in zone 2. When a permissive signal is received, instantaneous trip from the overreaching pilot zone is made. The GARD 8000 allows selection of either Zone 2 or Zone 3 as the overreaching Pilot Zone (Forward pilot zone). The Three Poles Open (breaker open) signal selection is included in the settings. To determine if the three poles have opened, three status contact inputs (corresponding to one for each pole) can be used, or one input can be used that corresponds to the three poles in series. There is a setting to select whether carrier send should be initiated by an open breaker, ‘Open breaker carrier send’. The time delay for this function is fixed to 100 ms. The ‘Dist carrier send extend time’ provides a minimum time for channel signal transmission. Channel tripping and channel activation can be disabled using a status contact input ‘Block pilot trip’. It also can be disabled for power swing conditions by the setting ‘Distance pilot power swing block’. Weak infeed logic enables carrier send and weak infeed trip according to the settings for this function.

Distance transientblock

ECHO distance

Carrier Receive

Forward pilot zone

Three Poles Open

Power swing block

Block pilot trip


Zone 1 Fault

100ms


0

T


Enable Distance pilotpower swing block



Figure 9-17. Permissive Overreach

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9.2.6 DIRECTIONAL COMPARISON BLOCKING (DCB) DCB is operating on the principle to use a communication channel to block tripping for external faults while no signal transfer is required for internal faults. This scheme is typically applied with ON/OFF Power Line Carrier and has the advantage of not being affected by a possible loss-of-signal for faults internal to the line. Power Line Carrier transmission uses the power line itself and there is a risk of a transmitted signal being shorted or interrupted by a fault on the same conductor or line.

The DCB scheme with directional start uses a reverse directional element to start and maintain a carrier block signal. The scheme requires a channel coordination timer, and a reverse distance zone (Zone 4). The coordination timer should be adjusted to accommodate maximum expected channel delay plus a margin to allow for variations of the pick up time of the forward pilot zone and the reverse blocking element.

21R (CARRIER TX)

21P 21R (CARRIER TX)

BKRA

BKRB

TRIP BKR A

CARRIER TX

+

CARRIERRX

T2A

21R21P

TRIP BKR B

CARRIER TX

+

CARRIERRX

T2B

21R 21P

coordinationtimer coordination

timer

21P 21R (CARRIER TX)

21P 21P 21R (CARRIER TX)

BKRA

BKRB

TRIP BKR A

CARRIER TX

+

CARRIERRX

T2A

21R21P

TRIP BKR B

CARRIER TX

+

CARRIERRX

T2B

21R 21P

coordinationtimer coordination

timer

21P 21P

Figure 9-18. Directional Comparison Blocking With Directional Carrier TX

Directional Comparison is activated when selected in the Protection Scheme setting. It will function as a complement to the Step Distance scheme. The main difference between this scheme and the others is that the channel signal is transmitted to block remote tripping instead of permitting it. Proper operation of this scheme requires that the measuring element used to activate the channel be selected as reverse. Therefore, if directional comparison is selected as the protection scheme, Zone 4 will be set as reverse, even if the setting is selected as forward.

August 1, 2009 9-21 973.334.3100



When a terminal unit on the transmission line detects a reverse fault, a channel signal (channel start) will be transmitted to avoid remote-end tripping by overreach elements (Zone 2 or Zone 3). Therefore, overreach tripping will occur when no channel signal is received. The channel signal is transmitted to the remote end by the terminal detecting the reverse direction fault. Correct application of this scheme requires that the following conditions are satisfied:

1. The distance covered by the reverse element must be longer than the distance covered by the forward overreach element of the remote end. This will avoid any Zone 2 (or Zone 3) tripping for a fault outside the line.

2. Overreach elements must be provided with a time delay (DCB distance coordination time) to allow the transmission of the channel signal between terminals.

Channel receive

Forward pilot zone

Power swingblocking

Block pilot trip

Input channel stop

Zone 1 Fault

Enable Distance pilotpower swing block



50P-1 Phase A

Reverse pilot zone(Z4)

50P-1 Phase B

50P-1 Phase C

50G-1 Ground

Fast carrier start

0

T

Distance extendtime

Distance protectionchannel stop

T

0

DCB distancecoordination time

Figure 9-19. Directional Comparison Blocking

The DCB scheme can also use ‘Fast carrier start’. The ‘Fast carrier start’ uses non-directional overcurrent elements to start carrier which enables faster trip (shorter DCB coordination time setting). The ‘Fast carrier start’ scheme uses step 1 instantaneous overcurrent elements, 50P-1/50G-1 in the diagram. For this scheme, the setting of these elements should be non-directional.

August 1, 2009 9-22 973.334.3100



The timer ‘Distance extend time’ should be set to avoid overreach elements tripping in case of transient reverse overcurrent after a fault has been cleared. The timer ‘DCB distance coordination time’ on the block diagram provides a coordination time delay to allow the transmission of the blocking channel signal between terminals in case of faults outside the protected line. Channel tripping and channel activation can be disabled using the status contact input ‘Block pilot trip.’ It can also be disabled for power swing conditions by enabling the Power swing blocking setting.

9.2.7 DIRECTIONAL COMPARISON UNBLOCKING (DCUB) The DCUB scheme was designed for Frequency Shift Power Line Carrier. The FSK carrier sends a continuous blocking (guard) signal. When a forward distance element detects a fault, the transmitted carrier frequency is shifted to a trip signal. The scheme is a permissive principle; forward operation AND received permission are required for a trip. To accommodate for a risk of losing the carrier signal in the fault on the line, an unblock trip window is provided. If the receiver does not detect any signal, neither block frequency (GUARD), nor trip frequency, the relay is allowed to trip from its forward distance element for a short period (150 ms) following loss-of-signal.

STATION “A” 21P (CARRIER KEY)

STATION “B” 21P (CARRIER KEY)

BKRA

BKRB

+CARRIER

RX “A”

OR

150 msONE-SHOT

LOSS OF CHANNEL

TRIP BKR A

+

T2A

“A” 21P

TRANSMITTRIP B

+CARRIER

RX “B”

OR

150 msONE-SHOT

LOSS OF CHANNEL

TRIP BKR B

+

T2B

“B” 21P

TRANSMITTRIP A

STATION “A” 21P (CARRIER KEY)

STATION “B” 21P (CARRIER KEY)

BKRA

BKRB

+CARRIER

RX “A”

OR

150 msONE-SHOT

LOSS OF CHANNEL

TRIP BKR A

+

T2A

“A” 21P

TRANSMITTRIP B

+CARRIER

RX “B”

OR

150 msONE-SHOT

LOSS OF CHANNEL

TRIP BKR B

+

T2B

“B” 21P

TRANSMITTRIP A

+CARRIER

RX “B”

OR

150 msONE-SHOT

LOSS OF CHANNEL

+CARRIER

RX “B”

OR

150 msONE-SHOT

LOSS OF CHANNEL

TRIP BKR B

+

T2B

“B” 21P

TRANSMITTRIP A

+

T2B

“B” 21P

TRANSMITTRIP A

Figure 9-20. Directional Comparison Unblocking

August 1, 2009 9-23 973.334.3100



Transient block

ECHO distance

Carrier Receive

Forward pilot zone

Three Poles Open

Power swing block

Block pilot trip


Zone 1 Fault

100ms

0 Enable open breakercarrier sending

0

T

Distance carriersend extend time

Enable Powerswing block pilot


Distanceprotection channel

start

Loss-of-guard

10

0

Unblock delay time

200

0

Carrier fail time

150

0

Unblock window

Carrier Fail

Figure 9-21. Directional Comparison Unblocking Diagram During normal operation, a ‘guard’ carrier signal is transmitted and received at the remote terminal. When a terminal detects a forward fault within its pilot zone, it issues a signal for the carrier to switch to trip frequency (Distance protection channel start). When the shift is recognized at the remote end, a ‘carrier receive’ signal is given to the receiving relay, and a ‘Distance protection pilot trip’ is issued as for a permissive overreach scheme. As for the permissive schemes, the carrier signal is continued for the time set by ‘Distance carrier send extend time’. The transient block logic ensures that overtripping is not taking place for current reversals on parallel lines. In case the carrier trip signal is lost in the fault on the line, the unblock logic comes into play. A ‘loss-of-guard’ AND no ‘Carrier receive’ provides a permissive trip signal to the distance relay after a short time delay; 10 ms. This delay is to avoid enabling the unblock logic for normal carrier switching from guard to trip operation. The permissive signal is held during the ‘Unblock window’ (150 ms).

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The unblock logic also supervises the state of the carrier. In case there is a continuous trip being received, an alarm will be issued after the time ‘Carrier fail time’ (200 ms).

9.2.8 TRANSIENT BLOCK LOGIC The transient block logic for current reversals prevents an overreaching zone to generate erroneous trips due to current reversals that may occur during sequential tripping of faults on a parallel line. The overreaching zone is blocked for a short adjustable time after detecting a fault in the reverse direction.

A B

Forward Pilot A

Permissive Signal from A to B Figure 9-22. Transient Block Logic

A B

Forward Pilot B

Permissive Signal from A to B

Breaker opened

Trip conditionsfulfilled

Figure 9-23. Transient Block Logic

Zone 4 fault

0

T

Transient block

Distance extendtime

Figure 9-24. Transient Block Logic Diagram The transient block logic is very simple. A fault in the reverse direction within Zone 4 reach creates a ‘Transient block’ signal that is used in the permissive overreaching pilot schemes (POTT, DCUB) to ensure that false tripping does not occur for current reversals. The blocking signal is held high for the time set on ‘Distance extend time’. The transient block logic needs to be enabled by the setting

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‘Distance transient block enable’. When transient block is enabled, Zone 4 is forced in the reverse direction regardless of its directional setting.

9.2.9 WEAK INFEED LOGIC Weak Infeed logic may be used with the permissive overreach scheme for cases when one of the terminal units has a weak supply and is not able to transmit the channel signal. An Echo function is available, which allows the channel signal to be transmitted to the remote-end terminal whenever a channel signal has been received from the remote-end terminal, and none of the blocking elements is activated. The Weak Infeed Scheme trip function must also be enabled. When both terminal units are under normal supply, this scheme behaves like the Permissive Overreach Scheme. A trip is generated when a fault is detected by the overreach elements (zone 2 or zone 3), the reverse-looking elements (zone 4) are deactivated, and the remote-end terminal has transmitted the channel signal. Once the remote-end channel signal has been received (and the overreach elements and the reverse-looking elements are not activated, indicating that the fault is inside the line), the terminal will transmit a signal back to the emitter (echo signal) allowing tripping. This signal allows the remote-end terminal to trip by their overreach elements. Proper operation of this scheme requires that the measuring element used to activate the channel is adjusted reverse. Therefore, if Weak Infeed is selected, Zone 4 will be set as reverse, even if the setting is selected as forward. As a complement, this scheme includes Weak Infeed Trip logic. A trip by this logic will occur when all of the following conditions are satisfied:

1. Channel signal is received (trip permitted). 2. Overreach elements (zone 2 or zone 3) and blocking elements (zone 4) are deactivated. 3. Undervoltage elements have picked up.

The channel receive signal is provided with a pick-up delay to prevent operation for spurious carrier signals. The time is set by ‘Security Time’. Weak feed trip is blocked by loss-of-potential (fuse fail) if this is set to ‘Enable LOP Block’. To ensure proper operation for reverse faults (as detected by Zone 4), the weak feed blocking function provided by these elements is drop-out delayed by the time set on ‘Distance extend time’. The carrier echo signal will be sent for 100 ms only. This avoids the risk of an echo signal continuing being sent from one terminal to the other, just to be echoed back.

August 1, 2009 9-26 973.334.3100



Carrier Receive

Forward pilot zone

Loss-of-potential

Echo

None

Zone 4 fault

Enable LOP Block

Trip Weak Infeed

Echo Distance

VA

VB

VC

Weak infeed Undervoltage Level

T

0

Security time

0

T

Distance extendtime

Distance Weak InfeedSettings

100 ms

Trip Weak InfeedC

Trip Weak InfeedB

Trip Weak InfeedA

Figure 9-25. Weak Infeed Logic

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The fault locator uses the phase selector to determine the type of fault. Then the algorithm for each type of fault determines the distance to the fault.

9.3 PHASE SELECTOR The phase selector uses two main algorithms. The first determines whether the fault is three-phase. This requires three simultaneous conditions:

1) High positive sequence component, that is, above 0.1 x In. 2) Low negative sequence current: meaning no more than 0.1 x In A and <10% of the positive-

sequence current. 3) Low zero-sequence current: no more than 0.08 x In and < 8% of the positive sequence

current. If the fault detected does not fulfill all the conditions of a three-phase fault, the second phase selector algorithm is executed. It compares the arguments of the negative and positive cycles. If the fault is not three-phase and meets the third condition for three-phase faults (low zero- sequence component), it can not be a ground fault. Therefore, it has to be two-phase. If, however, it does not meet the third condition for three-phase faults (high zero-sequence component), it must be a ground fault, single-phase or two-phase to ground. Faulted phases are determined by analyzing the angle: φ = arg(Ia2) − arg(Ia1_ f ) where: Ia2: Phase A negative sequence current. Ia1_f: Faulted phase A positive sequence current (once the load component is eliminated). The following figures represent the angle diagrams used to determine the phases involved in the fault by the φ angle.

Figure 9-26. Phase selector

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9.4 FAULT DETECTOR The distance relay is provided with a fault detector to supervise element operation. Operation of the fault detector is based on:

9.4.1 DETECTION OF INCREASE OF SEQUENCE CURRENTS The conditions which activate the fault detector are:

• An increase of the zero sequence current with respect to the value two cycles previously, and higher than 0.04 times nominal current.

• And increase of the negative sequence current with respect to the value two cycles previously, and higher than 0.04 times nominal current.

• More than 25% increase of the positive sequence current with respect to the value two cycles previously.

The fault detector will remain sealed for two cycles, plus an additional reset time of 30 ms. The fault detector is also kept sealed by assertion of any of the distance elements, overcurrent elements, stub bus, close into fault, and the trip signal.

9.5 LOSS-OF-POTENTIAL BLOCK If the PT secondary circuit fuses blow, the terminal unit will lose the corresponding analog voltage input. This situation may cause unwanted operation of the distance elements. Therefore, this condition must be detected and the measuring elements must be blocked before undesired tripping occurs. The Loss-of-potential threshold is 30 V. LOP logic operation is blocked when any breaker pole is open and if a fault detector is active. The loss-of-potential condition has a drop-out delay set by ‘LOP Reset time’ to prevent assertion of distance elements when the voltage is restored.

Fault Detector

Any pole open

VA

VB

VC

LOP < 30 V

T

0

LOP (Fuse fail)

LOP Reset time Figure 9-27. Loss-of-Potential Block

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9.6 OPEN POLE LOGIC The open pole logic detects the opening of any pole of the breaker, generating the corresponding outputs (A pole open, B pole open and C pole open), based not only on the condition of the breaker position contacts but also on the output of the three undercurrent detectors, one for each pole, whose levels are given by the following adjustments: A open pole current level, B open pole current level and C open pole current level. With the indication outputs of each pole, the open pole detector also generates the following outputs: ‘one open pole’, ‘three open poles’, or ‘any open pole’. The outputs of this unit are used by other functions such as pole discrepancy, close-into-fault, and reclosing. The type of open pole logic is selected on GARD 8000 under ‘Power Swing Block and Other Advanced Functions’; ‘Open Pole Selection’. The setting ‘3 inputs’ allows for individual 52b (or 52a) inputs, one for each phase. The GARD 8000 system logic may however use one 52 input that is mapped to the three phase selective inputs. It is also possible to use the setting ‘2 inputs’ which allows open pole detection to operate on either one 52b where the 3 phases are connected in AND or connected in OR.

IA

IB

IC

0

20

A open52b_A

52b_B

52b_C

B open

C open

1 pole open

3 poles open

Any pole open

Figure 9-28. Open Pole Logic with Individual 52b Inputs

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IA

IB

IC

0

20

A open

52b

B open

C open

1 pole open

3 poles open

Any pole open

Figure 9-29. Open Pole Logic with One Common 52b Input

9.7 CLOSE-INTO-FAULT The distance relay is provided with a Close-Into-a-Fault Detector, which generates a non-reclosing three-phase tripping signal when a fault is detected at the time a breaker close command is issued. Under such conditions, the fault is considered to be inside the line or it would have been cleared by the corresponding protection elements. This element will activate after a manual breaker closing operation:

1. After activation of the status contact input Manual Close signal, in case of a fault inside zone 2 or zone 3 (according to setting selection for ‘CIFT supervision zone’).

2. Following reclosing, in case of a fault inside zone 2 or zone 3 (according to setting selection for ‘CIFT supervision zone’) and when “Z1 ext after recl” is enabled.

3. Following closing (manual or reclose) for a positive sequence voltage below 50 V and current over the set value for ‘CIFT overcurrent pickup.’

The settings for the CIFT function are on page “Power Swing Block and other Advanced Functions. The overcurrent function provides a means to clear a fault when a distance measurement is not possible due to a lack of adequate polarization voltage, when the PTs are connected on the line side and closing into a 3 phase fault. The use of Zone 2/3 when possible (two and single phase faults) enables a higher overcurrent setting for the current element as only 3 phase faults need to be considered which increases security. In addition, the current elements used for Close-Into-Fault have a settable 2nd harmonic restraint.

August 1, 2009 9-31 973.334.3100



Reclose command

Manual Close

Zone 2

Zone 3

CIFT

Ia

Ib

Ic 2nd

2nd

2nd

V1

Z1 ext after recl

300 ms

300 ms

CIFT supervision zone Figure 9-30. Close-Into-Fault Block Diagram

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9.8 LOAD ENCHROACHMENT The GARD 8000 Distance Protection has dynamic mho characteristic which will expand with the source impedance. As it is not possible to control the resistive reach of the dynamic mho, there is a risk that the characteristic will fall into the load impedance on long, heavily loaded lines. To prevent this, a load encroachment characteristic is provided. The characteristic has individual settings for forward and reverse load, which enables fine tuning for the actual application. Generally, maximum forward and reverse load differs and the blocking zones should not be larger than necessary. The load encroachment characteristic provides blocking zones that will prevent an expanding mho characteristic from operation within the set zone.

Blocking zone

α1α2

R1R2

X

RLOAD AREALOAD AREA

Blocking zone

α1α2

R1R2

X

RLOAD AREALOAD AREA

Figure 9-31. Load Encroachment Characteristic

9.9 POWER SWING BLOCK UNIT Power swing conditions are disturbances produced by imbalances between generation and demand, which may originate from changes in the topology of the network, load variations, system faults, etc. Current and voltage variations, in magnitude as well as angle, during a power swing may result in distance relays measuring an impedance that falls within its operating characteristic. Power swings may be stable (dampened until reaching a new balance situation) or unstable (balance not recovered). In case of unstable power swings, it is necessary to separate the system, creating islands in which there is balance between generation and demand. For any power swing, it is necessary to block the trip of the distance units: if the swing is stable, a trip may convert this to unstable and if the swing is unstable, a controlled islanding should take place by trips in pre-determined locations rather than the line protection. The GARD 8000 distance relay includes a power swing unit to prevent tripping of the distance elements on stable power swings (block) and allow controlled tripping on unstable power swings (trip).

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The power swing detector bases its operation on the analysis of the transfer speed of the impedance point through the R-X diagram. In case of a fault, the transfer between the non-faulted condition and the fault condition presents a very high transfer speed of the impedance point (since this involves an electromagnetic phenomenon). The transfer of this same point in case of a power swing involves a much lower speed (given that this is an electromechanical phenomenon), which depends on the initial load, the difference between generation and demand, generator inertia, etc. The principle of operation is based on time measurement that the impedance locus takes to travel between the two quadrilateral zones, outer and middle. If this time is longer than a threshold (set by the power swing detection time setting) there is no system fault but rather a power swing. Once a power swing has been detected, if the Power swing Trip function has been enabled, it is determined if the swing is stable or unstable. If the measured impedance reaches an inner quadrilateral zone, the swing is considered unstable and allowed to generate a trip. The power swing detector has three units of phase-to-phase impedance measurement per zone. When the three poles of the breaker are closed, it is sufficient to verify one of these measuring units, for example, AB, given the symmetry of the power swing phenomenon. (For single pole trip applications, the opening of a pole disables the measuring units related to the open phase.) The power swing detector is based on three quadrilateral impedance zones; outer, middle, and inner. These are all formed by resistive blinders and reactance blinders. The ‘inner’ zone is only used for power swing trip. In case this function is not used, the setting is ignored.

Figure 9-32. Power swing Unit

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There are a number of settings associated with the Power swing element:

• Blinders angle. Characteristic angle for the power swing blinders (A in the above Figure) • Forward outer reach. • Forward middle reach. • Forward inner reach. The inner blinder is used for power swing tripping only. • Reverse outer reach • Reverse middle reach • Reverse inner reach. The inner blinder is used for power swing tripping only. • Right outer resistance • Right middle resistance • Right inner resistance. The inner blinder is used for power swing tripping only. • Left outer resistance • Left middle resistance • Left inner resistance. The inner blinder is used for power swing tripping only. • I1 supervision. The minimum required positive sequence current for release of power swing

measuring elements. • Power swing detection time. The swing detection time between the outer and middle blinders. • Power swing reset time. Reset time of the power swing condition. If the impedance locus

remains in the distance zone operating characteristic longer than this time, power swing blocking is inhibited and the relay will trip.

• Power swing trip type. Power swing tripping can be selected on the Way-In or Way-Out. • Way-In trip time. Time delay for the Way-In trip operation. • Power swing condition reset time. Reset time for the power swing condition following a swing

locus moving outside the outer blinder.

9.10 REMOTE OPEN BREAKER DETECTION The distance relay unit is provided with a remote breaker open detector, which generates a signal to instantaneously open the local breaker when the zone 2 element activates and the remote-end breaker has tripped three-pole. Under these conditions, the trip is instantaneous; since the fault is located inside the line (zone 2 elements adjusted over 100% of the length of the protected line). Detector operation is blocked under the following conditions:

1. The fault is detected by the zone 1 element at the local end; therefore, tripping is instantaneous.

2. The trip signal is activated. If this signal is activated before the detector output signal becomes activated, the trip signal will initiate tripping the breaker.

3. A three-phase fault occurs, since it is not possible to see beyond the fault. If the conditions above are not present, and when remote-end breaker opening is detected, a trip is permitted as long as the zone 2 element is activated and the zone 1 element is not activated. In case of faults inside zone 1, the zone 2 element will also be activated, even before the zone 1 element. Therefore, a time delay is implemented after the input of the zone 2 pickup signal.

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The remote breaker open detector is based on if there is a three-phase trip of the remote end during a non-three-phase fault, the current through any of the phases (one if the fault is phase-to-phase and two if the fault is single-phase-to-ground) will be very small (capacitive charging current only) while the remaining phase (s) will continue to detect the fault in zone 2. For this, the unit has an undercurrent unit whose level is given by the “Min current level” for the Remote Open Breaker function set in “Breaker settings.” In case of long lines, the capacitive current could exceed the minimum current setting and then the setting “Detection by capacitive current” should be used. The block diagram below shows the operation of the remote breaker open detector logic.

Fault detector

3 phase fault

Zone 1 fault

Trip

Zone 2 fault Trip Remote OpenBreaker

IA

IB

IC

10 ms

0

Remote openbreaker time

delay

Cap IA

Cap IB

Cap IC

Enable Cap current

T

0

Figure 9-33. Open breaker detector

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9.11 OVERCURRENT ELEMENTS The GARD 8000 includes a large number of overcurrent elements: • 3 phase instantaneous overcurrent measuring units (50P-1, 50P-2, 50 P-3) • 3 ground instantaneous overcurrent measuring units (50G-1, 50G-2, 50G-3) • 3 negative sequence instantaneous overcurrent measuring units (50Q-1, 50Q-2, 50Q-3) • 3 phase time overcurrent measuring units (51P-1, 51P-2, 51 P-3) • 3 ground time overcurrent measuring units (51G-1, 51G-2, 51G-3) • 3 negative sequence time overcurrent measuring units (51Q-1, 51Q-2, 51Q-3).

9.11.1 INSTANTANEOUS OVERCURRENT ELEMENTS The instantaneous overcurrent elements are measuring the RMS value of the analog current being fed to the unit. The unit assert when the RMS value exceeds 1.05 times the set value and resets at the pickup setting. The pickup activates the timer that integrates the measured values. The algorithm increases a counter depending on the input current. When the RMS falls below the pickup setting, a rapid reset of the integrator occurs. The activation of the output requires that the pickup current continue throughout the integration time; any reset returns the integrator to its initial condition so that a new operation initiates the time count from zero. The ground overcurrent element is operating on a 3I0 quantity calculated from phase RMS values according to the formula:

CBA IIII ++=03 The negative sequence overcurrent element is operating on an I2 quantity calculated from phase RMS values according to the formula:

312012401

2°∠⋅+°∠⋅+

= CBA IIII

Each instantaneous overcurrent element has an independent timer setting, All overcurrent units can individually be set directional, forward or reverse. Type of directional polarization is selectable either from the corresponding directional element or by Zone 2 torque control.

9.11.2 TIME OVERCURRENT UNITS The time overcurrent elements are measuring the RMS value of the analog current being fed to the unit. The unit assert when the RMS value exceeds 1.05 times the set value and resets at 1times the set value. The timing function is achieved by integrating the measured values. The integration is made by a counter that determines the time delay according to the set time curve.

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When the RMS value drops below the set pick-up value the integrator is reset. Assertion of the output from the unit requires that the pick-up remains active during the time of the integration; any reset causes the counter to reset so that a new pick-up starts over counting from zero. Time overcurrent units include a wide range of operation curves, which can be selected according to IEC and IEEE/ANSI standards: ANSI US • Moderately Inverse • Inverse • Very Inverse • Extremely Inverse • Short Term Inverse IEC

• Inverse • Very Inverse • Extremely Inverse • Long Term Inverse • Short Term Inverse

IEEE

• Moderately Inverse • Very Inverse • Extremely Inverse

In addition, the RI Inverse used for coordination with some electromechanical relays. The time dial setting for all the curves is from 0.05 – 10. However, the following restrictions apply:

• The IEC curves have a range of 0.05 – 1. If set to a value above 1, it will default to the maximum setting of 1. The increment is 0.01.

• All other curves (IEEE, ANSI, RI) have a range of 0.1 – 10. If set to a value below 0.1, it will default to 0.1. The increment for these curves is 0.1, even though the setting allows steps of 0.01. When set between 0.1 steps, the setting will be rounded to the nearest valid setting. For example, 2.33 will result in a setting of 2.30 and 2.37 will result in a setting of 2.40.

In addition to the above standard curves, a User defined curve can be applied. This curve needs to be created in the application program ZIVerCOM, saved in a file, and sent to the relay. There are 4 settings associated with a time overcurrent element; the type of curve, pick-up, time-dial and Minimum Time delay (or Fixed Time). When the curve type is selected to Fixed Time, only this setting is applicable.

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9.11.2.1 MINIMUM TIME DELAY Each curve can be configured with Minimum Operating Time Limit. This means that the selected curve is complemented with a fixed time portion so that regardless of the current magnitude, no trip can be made faster than the set minimum time. The Minimum Operating Time is set as the parameter Fixed Time.

Figure 9-34. Minimum Operating Time for time overcurrent curve

The Minimum Operating Time setting is not allowed to be larger than the curve’s operating time at 1.5 x pick-up. If this is the case, the fixed time setting is ignored and the operating time at this threshold is used as Minimum Operating Time. This is illustrated in the figure below.

Figure 9-35. Minimum Operating Time when set Fixed Time exceeds curve time delay at 1.5 x pick-up.

Note. It is important to realize that while the curves are defined for up to 20 times the input current (which is the set pick-up) it is not always possible to guarantee this range. The saturation limitation for the current channels are 160 phase-ground. Considering this limitation, the ‘times pick-up’ where the curves are valid is a function of the setting:

If 20160>

SetPUA the curve is guaranteed in it’s entire range (up to 20 times pick-up).

If 20160<

SetPUA the curve is guaranteed up to the actual multiple of the se pick-up of 160 A. For

example, an overcurrent element set with a pick-up of 40 A would follow the curve for up to 160/40 = 4 times pick-up When a current larger than 20 times pickup is applied to the relay, the trip time will be equal to that for 20 times.

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9.11.3 INVERSE CHARACTERISTIC CURVES

Figure 9-36. ANSI Moderately Inverse

0.02

0.0104(0.0226 )1S

t tdI

= +−

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Figure 9-37. ANSI Inverse

2

5.95(0.180 )1S

t tdI

= +−

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Figure 9-38. ANSI Very Inverse

2

3.88(0.0963 )1S

t tdI

= +−

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Figure 9-39. ANSI Extremely Inverse

2

5.67(0.0352 )1S

t tdI

= +−

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Figure 9-40. ANSI Short time

0.02

0.00342(0.00262 )1S

t tdI

= +−

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Figure 9-41. Inverse (IEC)

0.02

0.14( )1s

t tdI

=−

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Figure 9-42. IEC Very Inverse

13.5( )1s

t tdI

=−

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Figure 9-43. IEC Extremely Inverse

2

80( )1s

t tdI

=−

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Figure 9-44. IEC Long Inverse

120( )1s

t tdI

=−

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Figure 9-45. IEC short inverse

0.04

0.05( )1s

t tdI

=−

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Figure 9-46. IEEE Moderately Inverse

0.02

0.0515(0.114 )1S

t tdI

= +−

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Figure 9-47. IEEE Very Inverse

2

19.61(0.491 )1S

t tdI

= +−

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Figure 9-48. IEEE Extremely Inverse

2

28.2(0.1217 )1S

t tdI

= +−

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Figure 9-49. RI Inverse

110.339 0.236S

t td

I

⎡ ⎤⎢ ⎥⎢ ⎥= ⎢ ⎥⎛ ⎞

− ⋅⎢ ⎥⎜ ⎟⎢ ⎥⎝ ⎠⎣ ⎦

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9.11.4 DIRECTIONAL CONTROL OF OVERCURRENT UNITS The directional elements determine the direction in which the operating current is flowing in order to control the corresponding overcurrent element. All the directional element generate forward and reverse direction outputs which exercise directional control over the instantaneous and time overcurrent elements, as selected by settings. The overcurrent units can all be made directional, or torque controlled. There is an individual setting for each unit. Phase units can be selected to be • Non-directional • Forward by use of the phase directional element (67P) • Reverse by use of the phase directional element (67P) • Forward by use of Zone 2 (Z2), Note that the Zone 2 element should be set forward. • Reverse by use of Zone 2 (Z2). Note that the Zone 2 element should be set reverse. Ground units can be selected to be • Non-directional • Forward by use of the ground directional element (67N) • Reverse by use of the ground directional element (67N) • Forward by use of the negative sequence directional element (67Q) • Reverse by use of the negative sequence directional element (67Q) • Forward by use of Zone 2 (Z2G) • Reverse by use of Zone 2 (Z2G) Negative sequence units can be selected to be • Non-directional • Forward by use of the negative sequence directional element (67Q) • Reverse by use of the negative sequence directional element (67Q) • Forward by use of Zone 2 (Z2) • Reverse by use of Zone 2 (Z2)

9.11.5 POLARIZATION CONTROL When the polarizing quantity is too low for the directional elements to operate, the overcurrent units can be selected to be either blocked or allowed to trip non-directional. This is done by the setting ‘Loss of polarization block’ set to No (non-directional trip allowed) or Yes (overcurrent elements will not operated when polarization quantity is too low).

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9.12 DIRECTIONAL UNITS The GARD 8000 Distance module has the following directional elements:

• Phase directional unit (67P) • Ground directional unit (67G) • Negative sequence directional unit (67Q) • Zone 2 phase directional unit (used for Z2 torque control) • Zone 2 ground directional unit (used for Z2 torque control)

There are 2 settings for each of the three first elements; characteristic angle and minimum voltage. The three of them have one common setting; a transient block coordination timer for the directional overcurrent pilot schemes. The instantaneous units are enabled as soon as the directional elements is picked up, the time overcurrent units are enabled after the set coordination time. In addition, the zero sequence and negative sequence polarization voltages have a compensation factor setting in order to increase the measuring quantity. This gives higher sensitivity. The directional units are used for directional control of the overcurrent elements. At loss of polarization the overcurrent elements can be blocked or enabled for non-directional trip as determined by the setting ‘Loss of polarization block’. When this is set to No (release), the instantaneous elements are enabled immediately and the time overcurrent units after the set coordination time. The directional units assert when the directional element pick-up and when the level of polarization quantity exceeds the set threshold. The directional units initiate start of the timing of the overcurrent units. Should the directional element reset, the overcurrent unit timer is also reset and a new pick-up starts counting from zero. A trip requires uninterrupted directional operation for the duration of the timer. All directional elements are bi-directional, forward and reverse. All directional units can be blocked by a digital input signal. This block signal inhibits any release of non-directional operation of the overcurrent elements as well. If these are set directional, their operation will be blocked.

9.12.1 PHASE DIRECTIONAL UNIT There is one directional unit for each phase. The operating quantity is the phase current and the polarizing quantity is the memorized voltage between the other two corresponding phases as shown in the table. The memorized quantity is taken from 2 cycles preceding fault inception.

Table 9-13. Phase Directional Measurement

ABC Phase rotation Phase Operating quantity Polarizing quantity

A IA VBC = VB - VB CB IB VCA = VC - VAB

C IC VAB = VA - VBB

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The operating characteristic that consists of a straight line is shown. The operation zone is an area +/- 90 degrees from the set maximum torque angle. The angle is generally set to the complement of line’s positive sequence angle as shown in the example in the next section.

Blocking zone

Operating zone

Characteristic angle

Maximum torque

Operating phasor

Polarizing phasor

Figure 9-50. Vector diagram for the phase directional unit

The operating criterion is shown in the following table. ANG_67 is the set 67P characteristic angle

Table 9-14. Phase Directional Element

Phase Directional Element Phase Operating

quantity Polarizing quantity Criteria

A IA VBC = VB - VB CB IBB VCA = VC - VAC IC VAB = VA - VBB

-(90°-ANG_67)≤[arg(OP)-arg(POL)]≤(90°+ANG_67)

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9.12.1.1 APPLICATION EXAMPLE The following setting example illustrates how to select the characteristic angle for the phase directional unit. ABC phase rotation is assumed.

90-α

α

α90 - IA

VA

VC

VBαZIIA

VA

UBC

Figure 9-51. Application example

Assume a simple case with a line open at one end and with a A phase to ground fault without fault resistance. If the line impedance is Zlα, the fault current IA lags the voltage VA with an angle α. The phase directional unit does not use the phase voltage for polarization but the voltage between the other two un-faulted phases, i.e. VCB which is displaced from the faulted phase voltage by 90 degrees. If the angle between the operating and polarizing vector falls within the set characteristic angle α +/- 90 degrees, a forward operation is obtained. Consequently, the characteristic angle θ for a line with positive sequence angle α should be set to: θ = 90 - α or ANG_67 = 90° - ∠ZL1.

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9.12.2 GROUND DIRECTIONAL UNIT The operation of the ground directional unit is based on zero sequence quantities. The operating quantity is the zero sequence current and the polarizing quantity is the zero sequence voltage.

9.12.2.1 VOLTAGE POLARIZED GROUND DIRECTIONAL UNIT

Blocking zone

Operating zone

Characteristic angle

Operating phasor

Polarizing phasor

Figure 9-52. Ground directional characteristic with voltage polarization

The operating quantity is I0. The polarizing quantity is –V0+(I0 x set compensation factor) ∠(ANG_67G). The last term in the polarizing quantity is intended to increase the available polarizing quantity by boosting the magnitude. The operating criterion is given in the following table. ANG_67G is the set 67G characteristic angle. COMP is the set compensation factor.

Table 9-15. Directional Ground Element

Directional Ground Element Operating

phasor Polarizing phasor Criteria

I0 -V0+I0 x COMP ∠ANG_67G -(90°+ANG_67G)≤[arg(OP)-arg(POL)]≤(90-ANG_67G)

The minimum polarizing quantity is settable 0.05 – 10 V. The sensitivity of the operating quantity is 0.02 x IN (0.1 A for a 5A relay). If the magnitudes are below these thresholds, the unit will not be able to make a directional determination and the overcurrent units are blocked or allowed to issue a non-directional trip as selected by setting.

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The figure below shows the zero sequence network for a forward fault.

Figure 9-53. Zero Sequence Network for a Forward Fault

It can be deducted that V0 = ZA0 ⋅ (-I0) where ZA0 is the zero sequence impedance of the local source. Consequently, the angle between –V0 and I0 will be the angle of ZA0. For this reason, the 67G characteristic angle should be set to this value; ANG_67G = ∠ZA0. The relative phase difference between –V0 and I0 will determine the direction. However, a Zero sequence compensation factor may be used to increase the polarization phasor magnitude. When the zero sequence impedance of the local source is small, the V0 voltage may be below the 67G minimum voltage setting. In order to increase this voltage, a phase shifted compensation term, I0 x COMP is added to V0. The compensation value should be restricted so that misoperation does not occur for reverse faults. For faults in the reverse direction, V0 = (ZL0 +ZB0) ⋅ I0, where ZL0 is the line zero sequence impedance and ZB0 the zero sequence impedance of the remote source. If the angle of (ZL0 + ZB0) is close to ANG_67G, V0 and I0 ⋅COMP will be out of phase, and may even reverse its direction.

9.12.2.2 CURRENT POLARIZED GROUND DIRECTIONAL UNIT When current polarization is used, the characteristic angle used is 0°. In forward direction, the operating current I0 is rotated 180° with respect to the current flowing through the grounding and as the relay shifts the polarizing current with the same amount, I0 and IPOL are in phase for a forward fault. 67G_ANG should be set to 0°. The following table shows the operating criterion:

Table 9-16. Directional Ground Element (Current Element)

Directional ground element (current polarization) Operating phasor Polarizing phasor Criteria

I0 -Ipol -90°≤[arg(OP)-arg(POL)]≤90°

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9.12.3 NEGATIVE SEQUENCE DIRECTIONAL UNIT The operation of the negative sequence directional unit is based on calculated negative sequence current and voltage. The operating quantity is I2. The polarizing quantity is –V2+I2 x set compensation factor ∠(set angle). The last term in the polarizing quantity is intended to increase the available polarizing quantity by boosting the magnitude. The following table gives the operating criteria.

Table 9-17. Directional Negative Sequence Element

Directional Negative Sequence Element Operating

phasor Polarizing phasor Criteria

I2 -V2+I2 x COMP ∠ANG_67Q -(90°+ANG_67Q)≤[arg(OP)-arg(POL)]≤(90-ANG_67Q) The minimum polarizing quantity is settable 0.05 – 10 V. The sensitivity of the operating quantity is 0.02 x IN (0.1 A for a 5A relay). If the magnitudes are below these thresholds, the unit will not be able to make a directional determination and the overcurrent units are blocked or allowed to issue a non-directional trip as selected by setting.

Figure 9-54. Negative Sequence Network for a Forward Fault

For a forward fault, -V2 = ZA2 ⋅ (-I2) where ZA2 is the negative sequence impedance of the local source. Consequently, the angle between –V2 and I2 will be the angle of this impedance. ANG_67Q should be set to ∠ZA2.

9.12.4 ZONE 2 TORQUE CONTROL Zone 2 phase and ground elements can by used for torque control of the overcurrent units in the same way as the directional units.

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9.12.5 COORDINATION TIME FOR DIRECTIONAL UNITS The transient block coordination timer provided for all directional units is intended for use with the directional time overcurrent elements when they are applied in a pilot scheme. It provides transient block for current reversals in parallel lines. The timer should be set longer than the reset time of any carrier equipment used for communications.

9.13 DIRECTIONAL OVERCURRENT PILOT SCHEMES The GARD 8000 Pilot schemes can be complemented with similar logic for the directional ground and directional negative sequence elements. The schemes and logic available for these elements are

• Permissive Underreach transfer trip • Direct Transfer Trip • Permissive overreach Transfer Trip • Directional Comparison Unblocking • Directional Comparison Blocking • Weak Infeed Logic • Transient Block Logic

These pilot schemes are intended as complement to the distance pilot logic and provide higher sensitivity for high resistance ground faults. The carrier send signals can be combined in the logic to be the same signal as used for the distance relay pilot operation. In that case, careful consideration needs to be made that the schemes are compatible with each other, and that there are no system conditions that cause different directions of positive sequence current as compared to negative and zero sequence current. The ground and negative sequence pilot schemes can also use their own communication channel and then there are generally no coordination issues. The scheme logic is very similar to the distance element scheme logic. 67G-1/67Q-1 (step 1 instantaneous ground and/or negative sequence elements) is used as a ‘Zone 1’ element. Note that the pick-up setting for these elements should be high enough not to operate for fault outside the line. 67G-2/67Q-2 (step 2 instantaneous ground and/or negative sequence elements) is used as a ‘Zone 2’ element, overreaching. 67G-3/67Q-3 (step 3 instantaneous ground and/or negative sequence elements) is used as a ‘Zone 4’ element, overreaching in the reverse direction.

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Input disable 67 pilot

Channel receive

50 G-2

50 Q-2

50 G-1

Input block trip 67 pilot

50 Q-1

67G forward

67Q forward

50 G-3

67G-reverse

50 Q-3

67Q-reverse

0

T

0

TTrip 67 pilot

67 channel start

67 channel stop

DCB 67 delaytime

67 coord time

Figure 9-55. Directional Overcurrent DCB Scheme

9.14 STUB BUS PROTECTION The stub bus protection will clear faults instantly in the stub between the breaker (line CT) and the open line disconnect switch, with line PT on the line side of the switch. The stub bus function uses an input from a line disconnector 89b switch together with three phase current elements set as ‘Stub bus pickup’. When 89b is high and the current is above the set operating threshold, a trip will be generated after the set time delay.

89b

IA

IB

IC

T

0

Trip Stub Bus

Stub bus time delay

Figure 9-56. Stub Bus Protection

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9.15 BROKEN CONDUCTOR (PHASE UNBALANCE) UNIT (46) The broken conductor unit detects imbalance between phase currents of the protected line. It compares the negative sequence current with the positive sequence current, allowing for a more sensitive setting as the unit operates on the ratio I2/I1. A broken conductor algorithm taking only I2 into account would require a higher setting to account for higher imbalance at higher loads; operating on the ratio removes this compromise. The unit has settings for I2/I1 pick-up, time delay and minimum load current (I1) required. If load is below the I1 setting, the unit is blocked. This again allows for a more sensitive setting, as imbalance for very low load conditions can be proportionally larger. The 46 settings are made on the web page for “Misc. Current Elements.” The broken conductor unit is inhibited when a breaker pole is open.

9.16 THERMAL IMAGE UNIT Overhead lines and cables are capable of carrying significant overload for some period of time. While thermal image units are generally applied to transformers or generators, they do also have their place for line protection. A simple overcurrent can be set with a time delay but cannot take into account the effect of load prior to the overload event or repeated periods of overload shorter than the set time delay. An overloaded line is normally overloaded for a reason (other essential lines have tripped) and a trip for overload is undesirable if at all unavoidable. In order to provide as much restriction possible for overload tripping and still protect the line for damaging amount of overload, the GARD 8000 includes and overload protection with a thermal image. This unit provides both alarm and trip level settings. The thermal image is selected for the type of object (line/cable) and uses the set heating and cooling constants in its algorithm. The thermal image unit is measuring the current and by use of a thermal equation estimates the temperature of the object. When reaching set threshold, a trip and/or alarm signal is generated. The algorithm is based on modeling the heating of a resistive element by the current applied. If, following an overload of relatively short duration, the current drops below 0.5 A, a cooling constant is applied to ‘reset’ the element. The thermal image unit does not have a lower ‘start’ level, it is always asserted. The operating time depends on level of circulating current. The formula used for this calculation is:

dtdI θτθ ⋅+=2

where I is the applied current τ is the set time constant τ is defined as the time constant that will raise the temperature of the object from the initial θ0 to 63% of the final temperature of θ∞ as illustrated in the following figure.

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Figure 9-57. Thermal time constant

There is a setting that enables the GARD 8000 to memorize the temperature calculated in case of powering off the relay. If this setting is enabled, the thermal image algorithm’s start temperature will be the memorized value. The thermal image settings are located on the web page for “Misc. Current Elements.”

Figure 9-58. Thermal image characteristic time curves

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9.17 VOLTAGE UNITS The GARD 8000 provides a large number of voltage units: • 3 undervoltage units for each phase (27P) • 3 overvoltage units for each phase (59P) • 2 ground overvoltage units (59G)

9.17.1 PHASE UNDERVOLTAGE UNITS (27P) The GARD 8000 has three independent phase undervoltage units. The undervoltage units measure in each phase, and the output can be selected to be from each phase separately (OR) or for all three phases (AND). This setting selection is done independently for each of the three units: • AND: The unit trips when all three phase elements pick up • OR: The unit trips when any one of the three phase elements pick-up The three units also have independent time delay settings. The undervoltage elements pick up as soon as the measured voltage is below the set threshold, and a trip signal is issued if the voltage maintains a value below for the duration of the timer. As soon as the voltage rises above the set value plus the settable reset ratio (101-150%) the element and timer reset. The undervoltage elements may be blocked by “Any pole open” or LOP (loss-of-potential) logic, if selected by setting.

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Figure 9-59. Block Diagram for Phase Undervoltage units

9.17.2 PHASE OVERVOLTAGE UNITS (59P) The GARD 8000 has three independent phase overvoltage units. Each can be selected to measure on phase-ground or phase-phase voltage. The overvoltage units measure in each phase, and the output can be selected to be from each phase separately (OR) or for all three phases (AND). This setting selection is done independently for each of the three units: • AND: The unit trips when all three phase elements pick up • OR: The unit trips when any one of the three phase elements pick-up The three units also have independent time delay settings. A typical example for the overvoltage units could be:

• 59P-1 set to 1.2 times nominal voltage with AND logic and instantaneous trip • 59P-2 set to 1.1 times nominal voltage with OR logic and time delayed trip

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The overvoltage elements pick up as soon as the measured voltage is above the set threshold, and a trip signal is issued if the voltage maintains a value above for the duration of the timer. As soon as the voltage drops below the set value plus the settable reset ratio (50 - 99%) the element and timer reset.

Figure 9-60. Block Diagram for Phase Overvoltage units

9.17.3 GROUND OVERVOLTAGE UNITS (59) There are two ground overvoltage units, 59G-1 and 59G-2. Each unit has a pick-up setting and a timer setting. The ground voltage is computed from the phase voltages as: 3V0 = VA + VB + VC The overvoltage elements pick up as soon as the measured voltage is above the set threshold, and a trip signal is issued if the voltage maintains a value above for the duration of the timer. As soon as the voltage drops below the set value plus the settable reset ratio (50 - 99%) the element and timer reset.

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9.18 FREQUENCY UNITS (81) The GARD 8000 has 3 units each for Underfrequency (81m), Overfrequency (81M) and Rate-of-Change of Frequency (81D) for supervision or load shed applications. The frequency is calculated from one voltage channel. All frequency units have individual pick-up settings, delay time and drop-out time. In addition, there are 3 settings common to all frequency units: • Undervoltage inhibit. When the voltage is below the set threshold (2 – 150 V), the frequency

elements are blocked. • Activation time (pick-up time) set in number of half cycles. This setting determines the number

of half cycles used for measuring the frequency before a frequency condition can be declared. • Reset time (drop-out time) set in number of cycles. This determines the number of cycles used

to determine that the frequency has returned to a non-faulted condition. When the frequency units have picked up but not yet tripped, there could be a change in frequency of a short duration and this setting prevents the units from dropping out for such a condition.

9.18.1 OVERFREQUENCY UNITS (81M) The overfrequency units use phase A voltage to measure the frequency. They pick-up when the frequency exceeds 100% of set value for the set number of half cycles, following a frequency condition has been declared (set as a common setting). The drop-out is at 99.9% of set value for the duration of the set drop-out time set for the individual frequency unit.

9.18.2 UNDERFREQUENCY UNITS (81M) The underfrequency units use phase A voltage to measure the frequency. They pick-up when the frequency is below 100% of set value for the set number of half cycles, following a frequency condition has been declared (set as a common setting). The drop-out is at 100.1% of set value for the duration of the set drop-out time set for the individual frequency unit.

9.18.3 CHANGE OF RATE OF FREQUENCY UNITS (81D) The change of rate of frequency units use phase A voltage to measure the frequency. They have settings for underfrequency and rate-of-change of frequency pick-up levels. The underfrequency element picks up when the frequency is below 100% of set value the set the number of half cycles, following a frequency condition has been declared (set as a common setting). The underfrequency drop-out is at 100.1% of set value for the duration of the set drop-out time set for the individual frequency unit. The rate of change of frequency element picks up when the measured rate of change exceeds the set value + 0.05 Hz/s for set number of half cycles (set as a common setting), but a minimum of 5 cycles. The reason is that while frequency can be calculated over one cycle, rate of change of frequency needs 5 cycles for calculation. In case the set time is less than 10 half cycles, 5 cycles (10 half cycles) are still used.

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Figure 9-61. Rate of change of frequency

9.18.4 UNDERVOLTAGE BLOCK UNIT The undervoltage unit supervises the frequency units and blocks them for undervoltage conditions. This unit asserts when the voltage drops below 100% of set value, resetting at 105% of the setting if this condition persist during a time period of 10 cycles. Note that the relay can not determine the frequency for voltage below 10 V so for these conditions all frequency elements are blocked.

9.18.5 APPLICATION OF FREQUENCY UNITS When load and supply for a given portion of power systems are unequal, or not distributed equally, any type of a sudden generation or transmission deficiency may cause cascading outages. When the load in a balanced power system significantly exceeds generation, the system can survive only if enough load is separated from the system with a shortage in generation to cause generator output to be equal to or slightly above the connected load. Variations in frequency are caused by unbalance between generation and load. The reason for the unbalance is often one of the following: • Break up of the power system in sections • Unbalance between generation and load due to lack of running reserves • Loss of generation, trip of substations or lines for important interconnections

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Frequency is a reliable indicator of unbalance between generation and load. Any decrease in frequency is caused by excess loads. Under frequency relays are used for load shed in order to adjust the load to available generation to avoid a system collapse. When the frequency is restored to normal and the system has stabilized, the loads are reconnected. The restoration is made by using over frequency relays. Sufficient time delay should be employed to assure that the power system is stable prior to initiating load restoration. In areas where isolation of a large surplus of generation relative to connected load can be anticipated, automatic over frequency tripping of generation may be considered to prevent excessive high frequency and resultant uncontrolled generator tripping and equipment damage.

9.19 BREAKER FAILURE RELAY UNIT The breaker failure unit is used to detect failure of the breaker to open following a trip command and to give a trip signal to other circuit breakers to isolate the fault. The breaker failure unit incorporates a retrip function whose objective is to send a new tripping command to the failed breaker. The breaker failure unit uses six current detectors; two for each phase. One set is for the 1 Pole pickup setting and the other for the 3 Pole pickup. The breaker failure relay is capable of performing on a per phase basis in single pole trip applications. When applying GARD to three pole tripping, single phase pickup and three phase pickup should be set on the same value, as well as 1 Pole 50BF delay and 3 Pole 50BF delay. The current measuring elements are designed with a fast reset (<5 ms) in order to minimize the breaker failure timer setting. Breaker failure relay initiation is made by all GARD 8000 trips, but external initiation can also be made via an input. Both re-trip and breaker failure trip outputs are provided. Each of these has their individual time delay setting.

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BF_A 1 Pole

Trip A

3PH retrip

BF_B 1 Pole

BF_C 1 Pole

BF_A 3 Pole

BF_B 3 Pole

BF_C 3 Pole

Ext trip A

Trip B

Ext trip B

Trip C

Ext trip C

Trip 3PH

Ext trip 3PH

T1

0

T1

0

T1

0

T1_R

0

T1_R

0

T2_R

0

T2

0

BF Trip

A retrip

T1_R

0

B retrip

C retrip

Figure 9-62. Breaker Failure Relay

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9.20 SYNCH CHECK UNIT The synch check unit in GARD 8000 is used with the recloser and/or manual closing commands to determine if the two sides of the circuit breaker are synchronous with each other. Closing a circuit breaker out of synchronism may cause damage to the breaker or result in out of step conditions. The synch check function has two parts: • Synchronism check by comparing voltages on both sides of the breaker with regards to

magnitude, frequency and/or angle. • Energizing check by confirming that the voltage is low on one side (dead) and high on the other

(live). Settings for which direction this is allowed are available; D BUS/D LINE, H BUS/D LINE, D BUS/H LINE, H BUS/H LINE. To have the synch check function enabled, the H BUS/H LINE setting should be enabled in addition to the other type of energizing check selected.

Phase A line voltage is always used for the comparison. The bus voltage can be selected to be phase A, B or C. The voltage selected has to be entered in the settings so that the appropriate phase shift can be taken into account. Note that the “line voltage” refers to the side where the three phase VT used for the distance protection is located. In some applications this may be on the bus, while a single phase VT used for synch check is located on the line side. The angular compensation used is shown in the Table below.

Table 9-18. Angular Compensation

Line side Bus side ABC phase rotation VA VA 0º VA VB 120º B

VA VC 240º

9.20.1 VOLTAGE DIFFERENCE UNIT The voltage difference unit asserts when the difference between the bus and the line voltage is below the set threshold for this function. It resets at 105% of set value.

9.20.2 PHASE DIFFERENCE UNIT The phase difference unit asserts when the phase angle difference between the two voltages is below the set threshold. It resets at 105% of set value, or set value + 2 degrees, whichever is greater.

9.20.3 FREQUENCY DIFFERENCE UNIT The frequency difference unit asserts when the frequency difference between the two voltages is below the set threshold. It resets at set value + 0.01 Hz.

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9.20.4 ENERGIZING CHECK The energizing check unit allows closing of the circuit breaker when the voltage is high (live) on one side and low (dead) on the other. Two overvoltage elements with individual settings are used to determine the live condition and the dead condition. These elements assert at 105% of set value and resets at 100%. Note that the “line voltage” refers to the side where the three phase VT used for the distance protection is located. In some applications this may be on the bus, while a single phase VT used for synch check is located on the line side.

9.20.5 SELECTION OF SYNCH CHECK The recloser can be set to use the internal synch check element or an external synch check condition via a digital input.

9.20.6 APPLICATION OF SYNCH CHECK The synchronism check function is used to monitor the reconnection of the two parts of the circuit by breaker closing. It verifies that the voltages on both sides of the breaker (BUS and LINE) are within the magnitude, angle and frequency limits established in the settings. Verification of synchronism is defined as the comparison of the voltage difference of two circuits with different sources to be joined through an impedance (transmission line, feeder, etc.), or connected with parallel circuits of defined impedances. The voltages on both sides of a breaker are compared before allowing its closing so as to minimize possible internal damage due to a voltage difference in phase, magnitude and/or angle. This is very important close to steam-powered power plants where an unsynchronized closing of the line with considerable angle difference could cause serious damage to the shaft of the turbine. The difference in voltage level and phase angle at a given point in time is the result of the load between sources connected through parallel circuits and the impedance of the elements that join them. In interconnected systems, the angle difference between two sides of an open breaker is generally not significant since their sources are joined remotely by other elements (equivalent or parallel circuits). However, in islanded circuits, as in the case of an independent generator, the voltage angle, magnitude and/or frequency difference can be considerable.

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V_line

V_bus

Synch

Dead Line/Dead Bus

Dead Line/Live Bus

Live Line/Dead Bus

Live Line/Live BusSynch Check

Voltage difference

Phase difference

Frequency difference

Enable

‘1’

Enable

‘1’

Enable

‘1’

T

2 cycl

Figure 9-63. Synchro and Energizing Check Logic

9.21 POLE DISCORDANCE The pole discordance logic will detect an abnormality of the position of the three breaker poles. If this condition is maintained during the time setting, a three pole trip is generated. Given that the single-pole reclose cycles will produce a pole discordance condition, the time setting should be longer than the single pole reclose time. Pole discordance is enabled under the “Power Swing Block and other advanced settings.”

T

0

Trip polediscordance

52b_A

52b_B

52b_C

Figure 9-64. Pole Discordance Logic

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9.22 TRIP LOGIC The GARD 8000 Distance Relay trip logic combines all measuring elements set to produce tripping into one main TRIP signal.

Weak InfeedDistance

Distance Pilot Trip

Trip Open Phase(Broken concuctor)

Trip Undervoltage

Trip PoleDiscordance

OST

PhaseOvervoltage Trip

GroundOvervoltage Trip

Thermal Trip

Block Distance

Step Distance Trip

Distance Pilot Trip

Trip 50-1 Q

Trip 50-1 G

Pilot Trip 67

Trip 50Q

Trip 50G

Trip 51Q

Trip 51G

Trip 50P

Trip 51P

Weak Infeed 67

TRIP

Frequency Trip

Stub bus trip

Remote openbreaker (load loss)

Close-Into-Fault

Block Trip

Fault Detector

Pilot Trip 67

0

T

Phase A CurrentSupervision

Phase B CurrentSupervision

Phase C CurrentSupervision

Figure 9-65. Distance Module Trip Logic

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9.23 RECLOSING UNIT The GARD 8000 provides a recloser for up to 3 reclosing attempts with individual dead time and reset settings. It can work together with the built-in synch check unit or with an external unit via a digital input. The following reclosing modes can be set: 1P mode Only single pole reclosing is allowed. The recloser will lockout after a three pole trip.

Therefore, this mode has a single reclosing attempt, independent of the set number of attempts.

3P mode Only three pole reclosing is allowed, forcing the tripping logic to make all the trips of this type.

1P / 3P mode Both single and three pole reclosing is allowed. The first attempt will be either single pole or three pole, depending on the fault type. The remaining attempts (depending on the Reclosing Attempts setting) will always be three pole.

Dependent mode Only one reclosing will be attempted after a three pole trip. For single pole trips, the recloser will operate according to the number of attempts selected in the Reclosing Attempts setting.

Reclosing can be initiated by a large number of measuring units in the GARD 8000 as determined by setting.

9.23.1 RECLOSE INITIATE BY EXTERNAL TRIPS The recloser operates in the same manner for trips generated by the GARD 8000 distance protection or by external protection.

9.23.2 RECLOSING SEQUENCE START The Reclosing sequence starts for trips generated by any distance element or by any other element selected in the settings for Reclose Initiate. Sequence start is also generated by protection pilot trips or by external trips (when input External Protection Trip is programmed). In each case, sequence start will activate the signal RI. The Recloser Sequence Start logic will be blocked when the status contact input External Recloser Blocking is activated, or when the recloser attempts have exceeded the set limit. There is a setting for the type of external blocking used, ‘External Blocking’. ‘Recloser blocking type’ requires the blocking signal to be continuous. Unblock occurs when the blocking signal is removed. The setting ‘Pulse’ is used when the blocking signals is delivered as a pulse. Then also an unblock logic input needs to be used to unblock the recloser by another pulse.

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Zone 1

Zone 2

Zone 3

Zone 4

50P-1 RI

50P-2 RI

51P-1 RI

51P-2 RI

51P-3 RI

50G-1 RI

50G-2 RI

50G-3 RI

51G-1 RI

51G-2 RI

51G-3 RI

50Q-1 RI

50Q-2 RI

50Q-3 RI

51Q-1 RI

51Q-2 RI

51Q-3 RI

Open phase RI

Out of Step Trip RI

Remote BreakerOpen Enable

Step Distance

Reclose Initiate

50P-3 RI

CIFT

Reclose cycle inprogress

Distance Pilot Trip

67 Pilot Trip

Trip

External Trip

Block Recloser

Excessive numberof trips

Enable

Figure 9-66. Reclose Initiate Logic

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9.23.3 RECLOSING LOGIC Figure 8-67 depicts the flow diagram for the recloser operation. Figure 8-68 shows the block diagram of the recloser lockout.

Lock-out forDefinite Trip

Lock-out for OpenBreaker

CC = Reclose cycle in progressn = index number of reclose attemptN = number of set reclose attempts SIR = reclose initiate

ResetCC = 0n = 0

Start Time SIR - Reclose Initiate

52b = 1TRIP = 0

TRIP = 1SIR = 0

Lock-out for StartTime failure

SIR = 1TRIP = 152b = 0

CC = 1

SIR = 0TRIP = 052b = 1

Recl. Cycle Time (n)

Sync checksupervision (n)?

Sync = 1

Yes

Sync wait time(n)?

No

Sync wait timer (n)

Yes

Lock-out for lack ofsync

No

Sync = 0Recl = 1

No

Sync = 1

Fail to close time

Recl = 0

52b = 0

Lock-out forlack of sync

Security time

Lock-out fordefinite trip

n = N

Lock-out foropen breaker

52b = 1

Yes

SIR = 1n < N

n = n + 1

Figure 9-67. Reclosing Mode

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Any Lock-out State

Lock-out for CloseInto Fault

SIR = 0TRIP = 052b = 1

Manual close security time

Lock-out = 0

Reset

TRIP = 1

Figure 9-68. Recloser lock-out operation

The Reclose Initiate signal (SIR) starts a Start Time timer. If this timer times out while the SIR signal is still asserted, the trip signal is still active, or the breaker is still closed, the recloser goes into lock-out. The recloser remains in locked-out state until the breaker is manually closed for the time set on Security Time after Manual Close. The CC signal (reclosing in process) will remain activated during the entire recloser sequence, since the first attempt sequence (and any subsequent attempts) will continue until the recloser switches to the Reset or the Lockout state. A reclosing sequence (without synch check) is illustrated in the following Figure.

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Trip signal

Reclose initiate signal

Breaker open 52b

Recl. Cycle Time

Start time

Fail to Close Time

Security time

Fault inception Breaker trip

Start check

Reclosecommand

Reclose cyclecomplete

Breaker closedcheck

Breaker closedcheck

Figure 9-69. Recloser lock-out operation

9.23.4 RECLOSER TIMER (DEAD TIME) The Recloser Cycle Timer (dead time) is the time the breaker is allowed to remain open before a reclose is attempted. Activation of the Reclose Command signal (Recl) generates the breaker closing command signal. When the Start Time state is reached, the corresponding timer will be started:

• The First Three-Pole Recloser Cycle Timer will start for the first reclosing attempt after a three-pole trip.

• The Second or Third Recloser Cycle Timer will start for a second or third recloser cycle If the recloser is manually blocked before the timer has timed out, the recloser changes to the Recloser Reset status without reclosing. If the blocking signal is not activated during the timer countdown, the Sync Check state is reached.

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The Sync Check Supervision setting may be adjusted independently for each recloser cycle. If the Sync Check Supervision setting for the corresponding cycle is set to NO, the Reclose Command signal (Recl) is generated and the Fail to Close (inhibit) timer is started. In case the breaker does not close during the set time, further reclosing is blocked. If the Sync Check Supervision setting for the corresponding cycle is set to YES, the next step is to check the Sync signal, which indicates the presence of synchronous conditions. If this signal is activated, the Reclose Command signal (Recl) is generated and the Fail to close timer is started. When synchronous conditions are not reached (Sync deactivated), the Sync Wait Timer Enable setting is checked. If this setting is set to NO, the recloser changes to the Lock-out Due to Lack of Synchronism state. If the setting is set to YES, the Sync Wait Timer starts to count down the adjusted time. Activation of the Sync signal before timeout generates activation of the Reclose Command signal (Recl), and the Fail to Close timer is started. If the Sync signal is not activated before timeout, the recloser changes to Lock-out Due to Lack of Synchronism state.

9.23.5 FAIL TO CLOSE TIME When the recloser Fail to Close Time state is reached, the Reclose Command output (Recl) is activated to send a close command to the breaker, and an adjustable Fail to Close Timer is started. If the breaker closes before the Fail to Close Time is completed, the Recloser Reset Time state is entered. If the time is completed and the breaker remains open, the recloser state switches to Lock-out Due To Open Breaker. In either case, the Reclose Command output is subsequently de-activated.

9.23.6 SECURITY TIME When the Recloser Security Time state is reached, an adjustable Security Time timer is started. This setting is common for all the three reclosing cycles. The Security Time setting is used to determine whether two consecutive trips correspond to the same fault that has not been successfully cleared, or to two consecutive faults. If the Security Time is completed without a trip being initiated, the recloser switches to the Recloser Reset state, and the reclose attempt is completed. If a trip occurs and the Reclose Initiate signal (SIR) is activated before the Security Time is completed, the next step in the reclose sequence is determined by the Number Of Reclose Attempts (n) setting. If a trip occurs (SIR signal activated) after the last reclose attempt permitted by this setting, the recloser switches to Recloser Lock-out Due To Definite Trip. At this point, the reclose sequence ends. If the Recloser has not reached the last permitted reclose attempt, the trip signal that occurs before the Security Time is completed will initiate a new reclose attempt. The recloser will then switch to the Start Time state.

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9.23.7 RECLOSER LOCKOUT The previous sections in this chapter have described how the Recloser Lockout state is achieved when the Recloser cannot initiate a breaker closing attempt in response to fault conditions and corresponding trip operations. There is another condition that can produce Recloser Lockout; when the breaker is opened without a fault associated with the breaker operation, Recloser Lockout will also occur. Under this circumstance, the Recloser switches to Recloser Lock-out Due To Open Breaker, and reclosing is disabled. The Recloser will remain in the Recloser Lock-out Due To Open Breaker state until a closed breaker is detected or a Manual Close Command is initiated. The Recloser will then reset only if the breaker remains closed for the Manual Close Security Time set by the user. If a trip occurs before timeout, the Recloser switches to Recloser Lockout Due To Close Onto a Fault, and reclosing is disabled.

9.23.8 BLOCK RECLOSING The recloser can be manually blocked or unblocked with the Recloser Block command. If the recloser is in a reclose sequence when the Block Recloser command is received, further operations are suspended. No reclose attempts will be initiated after a breaker trip. The type of signal used for external block of the recloser can be set. ‘Recloser blocking type’ requires the blocking signal to be continuous. Unblock occurs when the blocking signal is removed ‘Pulse’ is used when the blocking signal is delivered as a pulse. Then also an unblock logic input needs to be used to unblock the recloser by another pulse.

9.23.9 DEFINITE TRIP A Definite Trip signal will be generated in the Recloser when the Recloser is blocked or, after the reclosing attempt sequence, the SIR (Recloser Initiate) signal is not asserted. The Definite Trip signal will remain activated as long as the element performing that trip does not reset. This usually happens when, after a trip, no reclosing attempt takes place. In this case, the recloser will change to Recloser Lockout Due to Definite Trip.

9.23.10 RECLOSER NOT IN SERVICE The Recloser is placed in the Not In Service state whenever the Recloser In Service Enable setting is NO. If a trip occurs under this condition, the Definite Trip Due to Disabled Recloser signal will be activated, generating the corresponding event in the Event Recorder.

9.23.11 RECLOSE COUNTER There is a counter accessible from the operator interface, which indicates the number of reclose attempts completed.

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9.23.12 SYNCHRONISM CHECK TYPE SELECTION Both the Recloser and the command logic (for opening and closing operations of the breaker) use the Sync signal, which indicates whether there are synchronous conditions prior to breaker closing. Such information is provided to the GARD 8000 distance protection module either by the synchronism unit included in the terminal unit or by an external device through the status contact input External Synchronism signal. The Sync Check setting ‘Internal/external sync check’ indicates which signal is being used for synchronism:

9.23.13 CLOSING COMMAND The direct output for breaker closing is activated when a Reclose Command (Recl) or a Manual Close Command is present. When the closing command is due to reclosing, the local control logic generates the Breaker Close signal, since synchronism is included in the Recloser logic. When the closing command is due to a manual operation through the HMI, or through communications (local or remote), the local control logic will check for synchronism (Sync signal), as long as the “Sync Check Supervision” setting for manual closing (web page 3.7.4, Breaker Failure) is set to YES. When synchronous conditions are not present (Sync de-activated), the local control logic generates the event “Closing Command Halted Due to Lack of Synchronism.” The local control logic is halted at this point. The local control logic generates the Closing Command signal and the Breaker Close signal when synchronous conditions are present (Sync activated), or when no synchronism supervision is performed (Sync Check Supervision is set to NO). Once the close signal is generated, the Close Fail Time starts counting down. The Close Command Failure signal will activate if the timer times out before detecting the Breaker Closed status signal. The corresponding event will be recorded in the Events Recorder.

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9.24 BREAKER SUPERVISION FUNCTIONS The GARD 8000 provides two functions useful for indicating need for breaker maintenance; total accumulated breaking current and excessive number of trips.

9.24.1 ACCUMULATED BREAKING CURRENT The GARD 8000 provides breaker supervision by calculating the square of the breaking current. The kA2 of the current is proportional to the actual energy opened by the breaker. The ‘breaker opening current’ is measured as the square of the maximum current between the time of the trip (or manual open command) and the time the breaker opens. There are two settings for this function: • Alarm level for accumulated kA2 • Actual kA2 The second setting is used to enter a ‘starting value’ for the calculated sum in case the breaker has been in service some time after maintenance before GARD 8000 is installed. It is also used to reset the sum following breaker maintenance.

9.24.2 EXCESSIVE NUMBER OF TRIPS The function for excessive number of trips limits the possibility of uncontrolled open and close operations of the breaker. The number of trips can be set to 1 - 40, and when the set number is exceeded during a 30 minute time period, further reclosing of the breaker is prevented by asserting the lock-out function in the recloser.

9.24.3 ARC DETECTOR This function detects an arc over an open breaker pole. When the breaker opens (as indicated by the 52b contact) and the current is above the set level for ‘Arc detector pick up’, the signal ‘Arc detector trip’ will be generated after the set time delay ‘Arc detector time’.

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9.25 SERIES COMPENSATED APPLICATIONS Faults which involve voltage reversal are common on lines with series compensation. These occur when the impedance from the voltage transformer position up to the fault point is capacitive. This voltage reversal results in erroneous directional decisions, given that all the directional units are designed assuming inductive relations between the operating current and the polarization voltage. The distance characteristics determine the direction of the fault, using positive sequence voltage as a polarization phasor. In most cases this voltage is not reversed in case of single pole or phase to phase faults, but may be in case of three phase faults, for which the use of memory voltage is necessary. When the series compensation logic is enabled, the positive sequence voltage with memory is always used whenever the fault detector is active, independent of the positive sequence voltage level at the time, given that a reversal of this voltage can be given with relatively high voltage. The duration of the voltage memory will be given by the Memory duration setting. In general, to correctly clear faults in a forward direction it is not necessary to use long memory times, because the voltage reversal does not tend to arise for faults in zone 2. The correct performance in case of reverse direction faults may, however, require very long memory times, which will depend on the operating times of the adjacent line protections in charge of clearing these faults. In order to avoid incorrect trips at the end of the voltage memory time, the distance relay incorporates a logic which allows to transiently blocking all directional units which supervise in a forward direction, once it is detected that the fault is in a reverse direction. While the distance relay is designed to be applied on series compensated lines, this version of GARD 8000 is not equipped with the logic for it. For series compensated line applications, please contact the factory. Note that there are settings for series compensated lines (Power Swing Block and Other Advanced Functions). These should not be enabled, unless recommended by the factory. There are special applications where the series compensated logic is useful even though the line is not compensated.

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Sequence of Events Reports and Fault Recording

SECTION 10. SEQUENCE OF EVENTS REPORTS AND FAULT RECORDING

10.1 MEASURED VALUES, TRIP STATUS, SEQUENCE OF EVENTS AND FAULT RECORDS

The Distance Protection module has its own Sequence of Event record, in addition to the System SOE. While a trip (and other trig signals as defined in the system logic) will trigger a system event, the distance SOE allows for more protection related details in the log. The Distance relay fault records give even more information about the fault condition, such as pre-fault and fault analog values.

10.2 MEASURED VALUES AND TRIP STATUS The GARD 8000 distance relay will display the measured values and trip status. The first screen provides a summary of status and whether DFR (oscillography), SOE records and Fault Reports are available.

Figure 10-1. Distance Measured Values

GARD 8000 Distance Relay RFL Electronics Inc. March 1, 2009 10-1 973.334.3100

Selecting ‘Metering Values’ brings up a screen with all analog values, measured and calculated. Note that the web browser will not automatically update these values. To get a new reading, refresh the browser window.



Figure 10-2. Distance Metering

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‘Unit Status’ displays the status of all measuring elements, whether they are in picked up state or not.

Figure 10-3. Distance Protection Unit Status

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“Recloser Status” displays which elements are active in the recloser logic.

Figure 10-4. Distance Recloser Status

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‘Last Trip Status’ displays which elements were active during the last trip event.

Figure 10-5. Distance Status at last trip

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10.2.1 SEQUENCE OF EVENTS 100 SOE’s are recorded in the Distance SOE, with the oldest numbered as #1 and the newest as #100. The record is accessed by selecting the distance relay module on the main status screen, and selecting Distance Sequence of Events. The events are time tagged from the system clock with a resolution of 1 ms. The distance elements that trigger an SOE record are defined in the ‘SOE Mask’ settings.

Figure 10-6. Distance SOE screen

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Selecting an SOE # button gives further details about the event, which elements were picked up with fault currents and voltages.

Figure 10-7. Distance SOE detail screen

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10.2.2 FAULT RECORDS The fault reports provide a summary of the most pertinent information for each fault event. This enables a quick overview of what caused the relay operation. 15 detailed fault records are stored.

Figure 10-8. Distance Fault Record

At fault inception, the following information is presented:

• Date and time stamp • Pre-fault currents and voltages as measured two cycles before the fault inception. The displayed

values include phase currents and phase voltages, neutral current and voltage and sequence quantities.

• Relay units asserted during the fault duration.

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At trip, the following information is presented: • Date and time stamp • Fault currents and voltages as measured two and a half cycles following the fault inception. The

displayed values include phase currents and phase voltages, neutral current and voltage and sequence quantities.

• Relay units tripped. • Distance to the fault. • Type of fault.

Figure 10-9. Distance Fault Record Details (Part 1 of 3)

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10.2.3 DIGITAL FAULT RECORDING The GARD 8000 provides powerful digital fault recording as part of the distance relay module. The oscillography is captured with 32 samples per cycles, up to a total of 15 seconds. The oscillographic records are stored in non-volatile memory. In case of loss-of-power, the records are guaranteed to remain in memory for a minimum of 27 days. Fault records are captured and stored in COMTRADE binary format, according to IEEE C37.111-1999. Any COMTRADE reader can be used for fault analysis, including the versatile Analyzer provided as part of the ZIVerCom Application program.

10.2.4 ANALOG AND DIGITAL CHANNELS The GARD 8000 distance relay module has nine analog channels: 5 currents and 4 voltages. They are:

3 PHASE CURRENTS 3 phase voltages 1 neutral current used for sensitive ground fault relaying or current polarization or the directional units 1 neutral current from a parallel line used for mutual coupling compensation of the fault locator 1 voltage input for a bus voltage used in the synch check unit The digital channels to be recorder are defined in the ‘Oscillography Mask’ settings.

10.2.5 TRIG CONDITIONS A digital fault record will be triggered by pick-up of any of the elements selected in the oscillography mask.

10.2.6 PRE-FAULT TIME The pre-fault time can be set between 0 and 25 cycles.

10.2.7 LENGTH OF OSCILLOGRAPHIC RECORD A maximum of 725 cycles can be recorded in the memory. The number of fault records depends on the length selected for the recording. Maximum number of records is 64 and they are related to the set length as shown in the Table below.

Table 10-1. Oscillographic Record

Set number of cycles Maximum number of records 725 1 350 2 175 3 ... ... 22 32 11 64

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10.2.8 DOWNLOAD OF COMTRADE OSCILLOGRAPHIC RECORD All DFR records are stored directly in COMTRADE format. To view a DFR records, it needs to be downloaded to a computer and the files opened with a viewer. The viewer can be any standard COMTRADE reader or the ZIVerCOM Analyzer provided with the GARD 8000 System. To download a DFR file ‘Retrieve Oscillography File from Distance Relay’ is selected from the Distance Relay Status screen. This opens a screen where the record to be downloaded and the format is selected. The data file can be either binary (smaller file) or ASCII.

10.3 FAULT LOCATOR The GARD 8000 distance protection module includes a fault locator. The algorithm compensates for load flow and uses an innovative steady state algorithm for very accurate distance to fault indication.

10.3.1 SETTINGS FOR THE FAULT LOCATOR

• Line Impedance, Local Source Impedance The following line parameters are used by the fault locator algorithm

o Positive sequence magnitude o Positive sequence angle o Zero sequence angle and K0 factor

All values are secondary ohms. • Line Length. The length is a unit-less value and corresponds to the next setting length units. • Line length units. Kilometers or miles. • Fault locator units. This parameter can be set to ‘length units’ and will then display the

measured km or miles. If set to % it will display the distance to the fault as a percentage of the line length.

• Indication zone. If set to ‘In’ the fault locator will display the distance for faults on the protected line only. When set to ‘In & Out’ it will display distance for all faults detected within any distance zone.

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Distance Relay Logic Programming


SECTION 11. DISTANCE RELAY LOGIC PROGRAMMING

11.1 OVERVIEW The GARD logic consists of two distinct parts; the System logic and the distance relay module logic. The System logic handles the interaction between different modules in the GARD chassis. For example: mapping of a physical input to a virtual input in the distance relay. The System logic can also perform manipulations on the signals delivered to and from the distance relay module. For example: providing trig points to the system SOE and latch of LED signals. The System logic can be user programmed. This is described in a separate logic programming manual. The section described here deals with programming inside the distance relay module only.

11.2 FACTORY DEFAULT PROGRAMMING The GARD System is delivered with default programming of both the System logic and the distance relay module logic, unless custom logic has been requested. The following section describes the default programming of the distance relay module. For System logic, please refer to the System manual and the System logic drawings supplied with the GARD. Note that the distance module factory supplied system logic uses labels for all signals connected between the system logic and the distance relay logic. This means that if the distance relay module is reprogrammed, the corresponding label should be changed in the system logic as well.

11.3 INPUTS The distance relay module has 70 pre-defined inputs. Some of these have logic associated with them.

11.3.1 BREAKER INPUTS (52 A OR 52 B) The breaker input logic enables connection of one or two circuit breakers. The GARD “Option settings” as described in the System manual are used to select single or dual breakers, 52a or 52b inputs. These settings need to be correct for the corresponding virtual input 52b to be supplied to the distance relay.

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11.3.2 PUSHBUTTON OPERATIONS The GARD can be supplied with an optional touch screen (TSD) user interface, and one of these screens displays soft buttons for pre-defined operations. The factory default logic configures 4 pushbuttons to operate:

• Reset oscillography • Block Trip (Cut-out) • Manual Close (Close CB) • Open CB

The Push Button Interface can be configured from the GARD System webpages, and also programmed to operate on other virtual inputs. Please refer to System Logic Programming Manual.

11.3.3 DEFAULT INPUT PROGRAMMING The following signals are supplied as standard. Note that any physical input can be connected to any number of virtual inputs via the input mapping pages. No Signal Option logic 1 RESET OSC PBI 2 BLOCK TRIP PBI 3 MANUAL CLOSE PBI 4 OPEN CB PBI 5 52 B Inverter /dual-single CB 6 89 B Inverter 7 TRIG OSC 8 21 PILOT BLOCK 9 67 PILOT BLOCK 10 21 CARRIER RECEIVE 11 21 LOSS OF GUARD 12 67 CARRIER RECEIVE 13 67 LOSS OF GUARD 14 EXTERNAL TRIP 15 EXTERNAL RECLOSE INITIATE 16 EXTERNAL LOP BLOCK 17 RECLOSE EXTERNAL BLOCK 18 RECLOSE EXTERNAL UNBLOCK 19 RECLOSE MANUAL BLOCK 20 RECLOSE MANUAL UNBLOCK 21 CLOSE TRIP CONTACT 22 EXTERNAL 50BF START 23 EXTERNAL 50BF-G START 24 EXTERNAL POLE DISCORDANCE 25 EXTERNAL SYNCH CHECK 26 INVERT DIRECTION 27 67G INHIBIT

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28 67P INHIBIT 29 67Q INHIBIT 30 BLOCK 50P-1 31 BLOCK 50P-2 32 BLOCK 50P-3 33 BLOCK 50G-1 34 BLOCK 50G-2 35 BLOCK 50G-3 36 BLOCK 50Q-1 37 BLOCK 50Q-2 38 BLOCK 50Q-3 39 BLOCK 51P-1 40 BLOCK 51P-2 41 BLOCK 51P-3 42 BLOCK 51G-1 43 BLOCK 51G-2 44 BLOCK 51G-3 45 BLOCK 51Q-1 46 BLOCK 51Q-2 47 BLOCK 51Q-3 48 BLOCK 27P-1 49 BLOCK 27P-2 50 BLOCK 27P-3 51 BLOCK 59P-1 52 BLOCK 58P-2 53 BLOCK 59P-3 54 BLOCK 59G-1 55 BLOCK 59G-2 56 BLOCK 81-1 ROC 57 BLOCK 81-2 ROC 58 BLOCK 81-3 ROC 59 BLOCK 81-1 OF 60 BLOCK 81-2 OF 61 BLOCK 81-3 OF 62 BLOCK 81-1 UF 63 BLOCK 81-2 UF 64 BLOCK 81-3 UF 65 BLOCK SYNCH CHECK UNIT

66 BLOCK 49 THERMAL IMAGE UNIT

67 BLOCK DISTANCE PROTECTION 68 OPEN I2 COUNTER RESET

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69 SETTINGS GROUP 1 70 SETTINGS GROUP 2 71 SETTINGS GROUP 3 72 SETTINGS GROUP 4 The virtual inputs can be reprogrammed as described later in this document. In the factory default programming, most of the inputs provide just a “straight” connection between a physical input and a logic input (Inputs 7 to 72). However, note that any physical input can be mapped to any number of logic inputs on the GARD mapping page. In the default programming, Inputs 1 to 4 are also programmed to the optional front Push Button Interface (PBI). This means that the logic input has a parallel path and can be asserted via a front push button, if so configured on the GARD PBI setting page. The default programming assigns logic Input 5 for a 52B function. The physical input can be a 52a or a 52b. In addition, the logic accommodates dual breaker inputs. The System logic provides the necessary logic for achieving this function, and appropriate settings need to be made on the GARD Option settings page.

11.4 OUTPUTS The factory default logic for the distance relay provides 64 virtual outputs. The system logic multiplies some of these, assigns triggers and latches them for use by LED indicators as shown in the following table.

No Signal LED

Number of outputs in the default system logic

Trig (Yes/No)

1 TRIP Latched 6 Y 2 BF RETRIP Latched 2 Y 3 BF TRIP Latched 4 Y 4 BREAKER CLOSE Latched 4 Y 5 RECLOSER LOCK OUT Latched 2 Y 6 PILOT TRIP Latched 1 Y 7 67 PILOT TRIP Latched 1 Y 8 WEAK INFEED TRIP 21 Latched 1 Y 9 WEAK INFEED TRIP 67 Latched 1 Y 10 50P TRIP Latched 1 Y 11 50G TRIP Latched 1 Y 12 50Q TRIP Latched 1 Y 13 51P TRIP Latched 1 Y 14 51G TRIP Latched 1 Y 15 51Q TRIP Latched 1 Y 16 27P TRIP Latched 1 Y

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17 59P TRIP Latched 1 Y 18 59G TRIP Latched 1 Y 19 CLOSE INTO FAULT TRIP Latched 1 Y 20 FUSE FAIL ALARM Latched 1 Y 21 POLE DISCREPANCY TRIP Latched 1 Y 22 46 TRIP Latched 1 Y 23 EXCESSIVE NO OF TRIPS Latched 1 Y 24 STUB BUS TRIP Latched 1 Y 25 81 UNDERFREQUENCY TRIP Latched 1 Y 26 81 OVERFREQUENCY TRIP Latched 1 Y 27 81 FREQUENCY RATE OF CHANGE Latched 1 Y 28 REMOTE OPEN BKR TRIP Latched 1 Y 29 CH START 21 Latched 1 Y 30 CH STOP 21 Latched 1 Y 31 CH START 67 Latched 1 Y 32 CH STOP 67 Latched 1 Y 33 OUT OF STEP BLOCK Latched 1 Y 34 THERMAL IMAGE TRIP Latched 1 Y 35 THERMAL IMAGE ALARM Latched 1 Y 36 OSC TRIGGERED Latched 1 Y 37 50P PICKUP Non-latched 1 N 38 50G PICKUP Non-latched 1 N 39 50Q PICKUP Non-latched 1 N 40 51P PICKUP Non-latched 1 N 41 51G PICKUP Non-latched 1 N 42 51Q PICKUP Non-latched 1 N 43 50 BF PICKUP Non-latched 1 N 44 STUB BUS PICKUP Non-latched 1 N 45 FAULT DETECTOR PICKUP Non-latched 1 N 46 SYNC CHECK OK Non-latched 1 N 47 FUSE FAIL PICKUP Non-latched 1 N 48 LOSS OF POLARIZATION Non-latched 1 N 49 46 PICKUP Non-latched 1 N 50 GR1 IN SERVICE Non-latched 1 N 51 GR2 IN SERVICE Non-latched 1 N 52 GR3 IN SERVICE Non-latched 1 N 53 GR4 IN SERVICE Non-latched 1 N 54 GROUND FAULT Latched 1 N 55 2 PHASE FAULT Latched 1 N 56 3 PHASE FAULT Latched 1 N 57 A Latched after trip 1 N 58 B Latched after trip 1 N

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59 C Latched after trip 1 N 60 G Latched after trip 1 N 61 Z1 Latched 1 N 62 Z2 Latched 1 N 63 Z3 Latched 1 N 64 Z4 Latched 1 N The virtual outputs can be reprogrammed as described later in this document. The factory default logic provides 6 logic outputs for the TRIP signal (Output 1), 2 each for BF RETRIP (Output 3) and RECLOSER LOCK OUT (Output 5) and 4 each for BF TRIP (Output 3) and BREAKER CLOSE (Output 4). All other outputs (6 to 64) are provided with 1 output each. All outputs are available for mapping of LED’s. As indicated in the table, some of these outputs are latched for LED operation.

11.5 ZIVERCOM Programming is made via an application program, Zivercom, supplied by RFL on request. This is a Windows based application that needs to be installed on a PC. In addition, the following files are needed and will be provided by RFL:

• Profile (Id.txt and cache_perfiles.txt and DR-C0000000.prp) to be copied to the directory c:\Program Files\Zivercom\datos\PerfilesProcome

• Configuration file (cfp) to be copied to c:\Program Files\Zivercom\Configuraciones • Language files (0091.e.idm and 0091.d.idm) to be copied to c:\Program

Files\Zivercom\datos\idiomas

This assumes that the Zivercom program is installed at the default location: c:\Program Files\Zivercom.

11.5.1 STARTING ZIVERCOM Zivercom is a powerful tool that is used for all of the latest generation relays made by ZIV. However, just a limited number of the functions provided are applicable to GARD. These functions make is possible to program the inputs and outputs from the distance relay module that interact with the GARD System Logic.

The password is ‘ziv’

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From the top menu, select IEDs > Emulate. This enters the offline programming mode. Select Model DR-C0000000 in the box that appears and click the right arrow (>) to put it in address 0.

If no Model shows up in the list, the DR-C000000.prp file has not been properly copied to \PerfilesProcome in the Zivercom program directory. Next, select the configuration. This is the cfp file provided by RFL and copied to \Configuraciones. In our example, we use the factory default logic DEFAULT_DEC_09_0.00_42264. Click OK. (The last digits of the cfp file are a check sum and automatically created by zivercom when saving the configuration. The actual file name entered was DEFAULT_DEC_09.) A new screen opens:

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Click the ‘+’ sign twice to open the menu and select ‘Configuration’:

Click on ‘Edit’. The next window gives a number of options in the top bar menu. Only ‘Logic’ is applicable for GARD:

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This is the work space where digital inputs and outputs are programmed. The operands will be addressed one by one. Only ‘Digital Inputs’ and ‘Digital Outputs’ are available as ‘Logic Type’. Both of these have an editable label field. The window then lists all of the logic inputs to the distance relay block and what signal they are presently programmed to assert in the distance relay logic. Digital Outputs are presented in the same way:

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The factory default programming provides 72 digital inputs and 64 digital outputs. All of them do not need to be used but it’s not necessary to delete them. Any signal programmed as input or output and not connected to the “outer world” will not interfere with anything. The number of assigned inputs (72) and outputs (64) should not be changed without consultation with RFL as this also influences the system logic.

11.5.2 PROGRAMMING OPERANDS A number of operands are provided. A Digital Input and Digital Output are used as inputs/outputs to the system logic while the Logic Input and Logic Output interacts with the logic within the distance relay module.

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CABLE – assigns a Digital Input/Output to a Logic Input/Output.

In the Input example, Digital Input 1 (mapped to a physical input via the System Logic) will clear oscillography.

March 1, 2009 11-11 973.334.3100



In the Output example, the Trip signal is connected to Digital Output 1 which then will be mapped to a physical output via the System Logic. CABLEM – Performs the same function as CABLE but one Digital Input can be connected to up to 16 Logic Inputs. Or, one Logic Output can be connected to 16 Digital Outputs. The inputs example above shows how CABLEM has been applied to a “breaker open” input where one Digital Input asserts 4 Logic Inputs. OR/AND – Performs this operation on up to 16 signals. For example, for the outputs above, all 50P elements have been combined (ORed) to one Digital Output. XOR – Performs this operation on two signals. FFRS – Provides a flip flop (SET, RESET) for two signals. There are other operands available in zivercom but these are not directly applicable for GARD. They perform advanced programming like timers, counters, combining of analog signals, etc. While possible to use for the GARD distance relay module, these operations are preferably programmed in the system logic.

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11.5.3 PROGRAMMING A DIGITAL INPUT OR DIGITAL OUTPUT To program a Digital Input, the input in question is first selected:

Then click Edit:

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The above example shows the CABLEM function where Digital Input 5 asserts 4 Logic Inputs. Note that any of these inputs can be inverted by the check box next to them. To add one more input, click a down arrow by an empty field. This opens up a box where signals are selected.

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The “Signal types” for this example should be ‘Logic input to protection’ and a list of all available signals is given in the drop down menu. (The entire list for available signals is attached at the end of this document.) Note that a ‘Logic input’ can only be selected once. If, for example, ‘Pole A Open Input’ should be connected to Input 6 instead of Input 5, it will first have to be deleted from Input 5. Deletion is made by checking the ‘Not used’ box. Save the new programming by ‘OK.’

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Outputs are programmed in the same manner. Note that also here, inversion check boxes are available for all signals.

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11.5.4 SAVING AND COMPILING THE CONFIGURATION To save the new programming, click ‘OK’ until the following screen shows up:

Here, select ‘Save’ from the file menu. Save as cfp.

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Before compiling, you need to load the new configuration in the previous screen. Select File, Exit.

Click in the New Value field, and select the configuration you just saved.

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Next, click on the ‘save’ icon. This creates a cpt file that is a database file used by zivercom. Zivercom needs this file for final compilation.

Then go back to Edit, File, Compile configuration. If no error text is displayed, the file compiled correctly and can be found in the directory \Configuraciones with the file name you gave the cfp file, just with a cmp extension. This is the file that will be loaded into GARD.

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11.5.5 LOADING THE COMPILED FILE INTO GARD The new programming, now compiled in a file name MANUAL.CMP in this example is ready to be loaded into a GARD. Select File operations from the main menu.

Send File to GARD 8000 – scroll down to ‘Distance Relay Module Logic Configuration’. Browse to locate the compiled file.

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Select it, and send to GARD.

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11.6 DISTANCE MODULE COMPLETE SIGNAL LIST Protection pickup output Default

50 Pickup

50 BF Breaker Failure pickup OUT 43

50G Unit 1 Pick Up OUT 38



50Q Unit 1 Pick Up OUT 39



51 Pick Up







59G Unit 1 Pick Up

59G Unit 2 Pick Up

81 Frequency Rate of Change Unit 1 Pick Up

81 Frequency Rate of Change Unit 2 Pick Up 81 Frequency Rate of Change Unit 3 Pick Up 81 Overfrequency Unit 1 Pick Up 81 Overfrequency Unit 2 Pick Up 81 Overfrequency Unit 3 Pick Up 81 Underfrequency Unit 1 Pick Up 81 Underfrequency Unit 2 Pick Up 81 Underfrequency Unit 3 Pick Up AB Zone 1 Pick Up AB Zone 2 Pick Up AB Zone 3 Pick Up AB Zone 4 Pick Up AG Zone 1 Pick Up AG Zone 2 Pick Up AG Zone 3 Pick Up AG Zone 4 Pick Up BC Zone 1 Pick Up

BC Zone 2 Pick Up

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BC Zone 3 Pick Up BC Zone 4 Pick Up BG Zone 1 Pick Up BG Zone 2 Pick Up BG Zone 3 Pick Up BG Zone 4 Pick Up Breaker Failure Ground Pick Up CA Zone 1 Pick Up CA Zone 2 Pick Up CA Zone 3 Pick Up CA Zone 4 Pick Up CG Zone 1 Pick Up CG Zone 2 Pick Up CG Zone 3 Pick Up CG Zone 4 Pick Up OUT 49 Open Phase Detector Pick Up Overreaching Zone Pick Up Phase A 27P Unit 1 Pick Up Phase A 27P Unit 2 Pick Up Phase A 27P Unit 3 Pick Up OUT 37 Phase A 50P Unit 1 Pick Up OUT 37 Phase A 50P Unit 2 Pick Up OUT 37 Phase A 50P Unit 3 Pick Up OUT 40 Phase A 51P Unit 1 Pick Up OUT 40 Phase A 51P Unit 2 Pick Up OUT 40 Phase A 51P Unit 3 Pick Up Phase A 59P Unit 1 Pick Up Phase A 59P Unit 2 Pick Up Phase A 59P Unit 3 Pick Up Phase B 27P Unit 1 Pick Up Phase B 27P Unit 2 Pick Up Phase B 27P Unit 3 Pick Up OUT 37 Phase B 50P Unit 1 Pick Up OUT 37 Phase B 50P Unit 2 Pick Up OUT 37 Phase B 50P Unit 3 Pick Up OUT 40 Phase B 51P Unit 1 Pick Up OUT 40 Phase B 51P Unit 2 Pick Up

Phase B 51P Unit 3 Pick Up OUT 40

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Phase B 59P Unit 1 Pick Up Phase B 59P Unit 2 Pick Up Phase B 59P Unit 3 Pick Up Phase C 27P Unit 1 Pick Up Phase C 27P Unit 2 Pick Up Phase C 27P Unit 3 Pick Up OUT 37 Phase C 50P Unit 1 Pick Up OUT 37 Phase C 50P Unit 2 Pick Up OUT 37 Phase C 50P Unit 3 Pick Up OUT 40 Phase C 51P Unit 1 Pick Up OUT 40 Phase C 51P Unit 2 Pick Up OUT 40 Phase C 51P Unit 3 Pick Up Phase C 59P Unit 1 Pick Up Phase C 59P Unit 2 Pick Up Phase C 59P Unit 3 Pick Up Remote Breaker Open Detector Pick Up Single Pole Trip Breaker Failure Phase A Supervision Pick Up Single Pole Trip Breaker Failure Phase B Supervision Pick Up Single Pole Trip Breaker Failure Phase C Supervision Pick Up OUT 44 Stub Protection Pick Up Three Phase 27P Unit 1 Pick Up Three Phase 27P Unit 2 Pick Up Three Phase 27P Unit 3 Pick Up

Three Phase 59P Unit 1 Pick Up



Three Pole Trip Breaker Failure Phase A Supervision Pick Up

Three Pole Trip Breaker Failure Phase B Supervision Pick Up

Three Pole Trip Breaker Failure Phase C Supervision Pick Up

Zone 1 Ground Units Pick Up

Zone 1 Phase Units Pick Up







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Protection trip outputs Default

50 Trip

50G Unit 1 Trip OUT 11



50Q Unit 1 Trip OUT 12



51 Trip









67G/Q Pilot Scheme Trip OUT 17

81 Frequency Rate of Change Unit 1 Trip OUT 27



81 Overfrequency Unit 1 Trip OUT 26



81 Underfrequency Unit 1 Trip OUT 25



A Pole Trip

B Pole Trip

C Pole Trip

Close Into Fault OUT 19

Distance Pilot Scheme Trip OUT 6

Open Phase Detector Trip OUT 22

Out-of-Step Trip

Phase A 27P Unit 1 Trip OUT 16




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Phase A Weak Infeed Trip 67G/Q

Phase A Weak Infeed Trip Distance

Phase B 27P Unit 1 Trip OUT 16












Phase B Weak Infeed Trip 67G/Q

Phase B Weak Infeed Trip Distance

Phase C 27P Unit 1 Trip OUT 16












Phase C Weak Infeed Trip 67G/Q

Phase C Weak Infeed Trip Distance

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Pole Discrepancy Trip OUT 21

Remote Open Breaker Trip OUT 28

Step Distance Activation

Stub Bus Protection Trip OUT 24

Thermal Image Trip OUT 34

Three Phase 27P Unit 1 Trip






Three Phase Trip

Trip OUT 1

Weak Infeed Trip 67G/Q OUT 9

Weak Infeed Trip Distance OUT 8

Zone1 Step Distance Trip



Zone4 Step Distance Trip Generic Protection Output Default

27P Unit 1 Enabled

27P Unit 2 Enabled

27P Unit 3 Enabled

49 Thermal Unit Enabled

50 BF Breaker Failure OUT 3

50 BF Breaker Failure Recloser Lock Out

50 BF Breaker Failure Unit Enabled

50G Unit 1 Enabled

50G Unit 1 Pick Up Condition

50G Unit 2 Enabled


50G Unit 3 Enabled


50P Unit 1 Enabled

50P Unit 2 Enabled

50P Unit 3 Enabled

50Q Unit 1 Enabled

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50Q Unit 2 Enabled

50Q Unit 3 Enabled

51G Unit 1 Enabled


51G Unit 2 Enabled


51G Unit 3 Enabled


51P Unit 1 Enabled

51P Unit 2 Enabled

51P Unit 3 Enabled

51Q Unit 1 Enabled

51Q Unit 1 Pick Up Condition

51Q Unit 2 Enabled


51Q Unit 3 Enabled


59G Unit 1 Enabled

59G Unit 2 Enabled

59P Unit 1 Enabled

59P Unit 2 Enabled

59P Unit 3 Enabled

67G Forward Direction

67G Reverse Direction

67 Time Delayed Forward Direction

67G Time Delayed Reverse Direction

67G/Q Pilot Scheme Channel Send OUT 31

67G/Q Pilot Scheme Channel Stop OUT 32

67G/Q Pilot Scheme Echo Keying

67G/Q Transient Block

67Q Inst Forward Direction

67Q Inst Reverse Direction

67Q Time Delayed Forward Direction

67Q Time Delayed Reverse Direction

81 Frequency Rate of Change Unit 1 Enabled



81 Overfrequency Unit 1 Enabled

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81 Underfrequency Unit 1 Enabled



AB Fault OUT 57, 58

AB Zone 1 Characteristic




ABG Fault OUT 57, 58

AG Fault OUT 57

AG Zone 1 Characteristic




Any Pole Open

Arc Detector

Arc Detector Enabled

BC Fault OUT 58, 59

BC Zone 1 Characteristic




BCG Fault OUT 58, 59

BG Fault OUT 58

BG Zone 1 Characteristic




Block Command Recloser Lock Out

CA Fault OUT 57, 59

CA Zone 1 Characteristic




CAG Fault OUT 57, 59

CC Voltage Supervisor Failure

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CG Fault OUT 59

CG Zone 1 Characteristic




Close Into Fault Recloser Lock Out

Close onto Fault Enabled

Directional 50Q Unit 1 Pick Up Condition



Dist Prot Transient Block

Distance Prot Echo Keying

Distance Protection Channel Start OUT 29

Distance Protection Channel Stop OUT 30

Distance Unit Zone 1 Enabled




External Three Pole Trip

External Trip

Fail to Close Recloser Lock Out

Fault Detector Activation OUT 45

Ground Fault OUT 54

Hot Bus

Hot Line

Hot Bus Hot Line Close Permission

Internal Zone Activation

LOP Block Trip OUT 20

LOP Detector Block

LOP Detector ON OUT 47

Latched Breaker Failure

Load Enchroachment Blocking

Load Enchroachment Enabled

Loss of polarization 21 OUT 48

Loss of polarization for 67Q Directional Unit OUT 48

Loss of polarization for Ground Directional Unit OUT 48

Loss of polarization for Phase A Directional Unit OUT 48

Loss of polarization for Phase B Directional Unit OUT 48

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Loss of polarization for Phase C Directional Unit OUT 48

Medium Zone Activation

One Pole Open

Open Breaker Recloser Lock Out

Open I2 Counter Alarm

Open phase detector Enabled

Out-of-Step Block Condition

Out-of-Step Block Detector Enabled

Out-of-Step Trip Condition

Out-of-Step Block OUT 33

PLC Equipment Failure

Permanent Trip Recloser Lock Out

Permanent Trip by Recloser Out of Service

Phase A 50P Unit 1 Pick Up Condition






Phase A 67P Forward Direction

Phase A 67P Reverse Direction

Phase A Retrip OUT 2

Phase A Time Delayed Forward Direction

Phase A Time Delayed Reverse Direction

Phase B 50P Unit 1 Pick Up Condition






Phase B 67P Forward Direction

Phase B 67P Reverse Direction

Phase B Retrip OUT 2

Phase B Time Delayed Forward Direction

Phase B Time Delayed Reverse Direction

Phase C 50P Unit 1 Pick Up Condition



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Phase C 67P Forward Direction

Phase C 67P Reverse Direction

Phase C Retrip OUT 2

Phase C Time Delayed Forward Direction

Phase C Time Delayed Reverse Direction

Phase Fault OUT 55

Phase-phase Fault OUT 55

Pole A Open

Pole B Open

Pole C Open

Pole Discrepance Unit Enabled

Reclose Command

Reclose Counter at Zero

Recloser Block Command

Recloser Lock Out OUT 5

Recloser Start

Recloser Unblock Command

Remote Breaker Open Detector Enabled

Series Compensated Lines Logic Enabled

Stub Protection Detector Enabled

Synchrocheck Close Permission OUT 46

Synchrocheck Frequency Slip Close Permission

Synchrocheck Lock Out

Synchrocheck Phase Difference Close Permission

Synchrocheck Unit Enabled

Synchrocheck Voltage Difference Close Permission

Synchrocheck Unit

Thermal Image Alarm OUT 35

Three Phase Fault OUT 56, 57, 58, 59

Three Phase Retrip OUT 2

Three Pole Trip Enable

Three Pole Trip Recloser Lock Out

Three Poles Open Input

Transient Block for Series Compensated Lines

Trip Direction AB Supervision Units Pick Up

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Trip Direction AG Supervision Units Pick Up

Trip Direction BC Supervision Units Pick Up

Trip Direction BG Supervision Units Pick Up

Trip Direction CA Supervision Units Pick Up

Trip Direction CG Supervision Units Pick Up

Trip Reverse Direction AB Supervision Units Pick Up

Trip Reverse Direction AG Supervision Units Pick Up

Trip Reverse Direction BC Supervision Units Pick Up

Trip Reverse Direction BG Supervision Units Pick Up

Trip Reverse Direction CA Supervision Units Pick Up

Trip Reverse Direction CG Supervision Units Pick Up

Zone 1 Fault OUT 61

Zone 2 Fault OUT 62

Zone 2G inst Forward Direction

Zone 2G Inst Reverse Direction

Zone 2G Time Delayed Forward

Zone 2G Time Delayed Reverse

Zone 2P inst Forward Direction

Zone 2P Inst Reverse Direction

Zone 2P Time Delayed Forward

Zone 2P Time Delayed Reverse

Zone 3 Fault OUT 63

Zone 4 Fault OUT 64 Logic Input to Protection Default

49 Thermal Image Block Input IN 66

49 Thermal Image Dropout Input

50G Unit 1 Torque Control disabling



50P Unit 1 Torque Control disabling



50Q Unit 1 Torque Control disabling





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67G/Q Carrier Receive IN 12

67G/Q Carrier Stop Input

67G/Q Loss of Guard Input IN 13

67Q Directional Inhibit IN 29

Any Pole Open Input

Block 27P Unit 1 IN 48



Block 50G Unit 1 IN 33






Block 50Q Unit 1 IN 36

















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Block 81 Frequency Rate of Change Unit 1 IN 56



Block 81 Overfrequency Unit 1 IN 59



Block 81 Underfrequency Unit 1 IN 62



Block Distance Protection Input IN 67

Block Synchrocheck Unit IN 65

Block Trip Input IN 2

Channel Trip Block Input for 67G/Q IN 9

Channel Trip Block Input for Distance IN 8

Close Trip IN 21

Console

Contacts Position BF Pick Up Input IN 22

Disable 50Q Unit 1

Disable 50Q Unit 2

Disable 50Q Unit 3

Disable 51G Unit 1

Disable 51G Unit 2

Disable 51G Unit 3

Disable 51P Unit 1

Disable 51P Unit 2

Disable 51P Unit 3

Dist Prot Carrier Receive Input IN 10

Dist Prot Loss of Guard Input IN 11

Enable Three Pole Trip Input

External Manual Close Input IN 3

External Protection Phase A Trip Input IN 14

External Protection Phase B Trip Input IN 14

External Protection Phase C Trip Input IN 14

External Reclose Input IN 15

External Synchrocheck Input IN 25

Ground Directional Inhibit IN 27

Ground Unit BF Pick Up IN 23

Invert Polarization IN 26

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LOP Detector Input IN 16

Line Isolator Open Input IN 6

Local

Open Command IN 4

Phase Directional Inhibit IN 28

Pole A Open Input IN 5

Pole B Open Input IN 5

Pole C Open Input IN 5

Pole Discordance IN 24

Recloser External Blocking IN 17

Recloser External Unblocking IN 18

Remote

Reset Latched Breaker Failure

Three Poles Open Input IN 5

Trip

Zone 2 directional unit blocking Inhibit Command sequence Default

Delete Oscillography Command IN 1

Distance Reset

Manual Close Command IN 3

Manual Open Command IN 4

Open I2 Counter Reset Command IN 68

Reclose Counter Reset Command

Recloser Manual Block Command IN 19

Recloser Manual Unblock Command IN 20

Settings Group 1 by Communications

Settings Group 1 by Digital Input IN 69







Settings Group Change by Communications Disable

Settings Group Change by HMI Disable

Trip Indication Reset Command

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Module Enable Control Default

49 Thermal Unit Enable Input

Arc Detector Enable Input

Close onto Fault Enable Input

Digital PLL Enable Input

Distance Unit Zone 1 Enable Input




Enable 27P Unit 1

Enable 27P Unit 2

Enable 27P Unit 3

Enable 50 BF Breaker Failure Unit

Enable 50G Unit 1

Enable 50G Unit 2

Enable 50G Unit 3

Enable 50P Unit 1

Enable 50P Unit 2

Enable 50P Unit 3

Enable 50Q Unit 1

Enable 50Q Unit 2

Enable 50Q Unit 3

Enable 51G Unit 1

Enable 51G Unit 2

Enable 51G unit 3

Enable 51P Unit 1

Enable 51P Unit 2

Enable 51P Unit 3

Enable 51Q Unit 1

Enable 51Q Unit 2

Enable 51Q Unit 3

Enable 59G Unit 1

Enable 59G Unit 2

Enable 59P Unit 1

Enable 59P Unit 2

Enable 59P Unit 3

Enable 81 Frequency Rate of Change Unit 1


March 1, 2009 11-39 973.334.3100




Enable 81 Overfrequency Unit 1



Enable 81 Underfrequency Unit 1



Enable Open Phase Detector

Enable Oscillography

Enable Synchrocheck Unit

LOP Detector Enable Input

Load Enchroachment Enable

Out-of-Step Detector Enable Input

Pole Discrepancy Enable Input

Remote Open Breaker Detector Enable Input

Series Compensated Logic Enable Input

Stub Protection Detector Enable Input Others Default

Any Unit Picked Up

Change of Settings Initialization

Close Command OUT 4

Close Command Cancelled

Close Command Failure

Equipment Cold Start Up

Equipment Manual Start Up

Equipment Ready

Equipment Warm Start Up

Excessive Number of Trips OUT 23

Frequency Disabled by Low Voltage

HMI Access

Open Command

Open Command

Open Command Failure

Oscillography External Trigger IN 7

Oscillography Triggered OUT 36

Pole A Open Command

Pole A Open Command Failure

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Pole B Open Command

Pole B Open Command Failure

Pole C Open Command

Pole C Open Command Failure

Protection Trip

Protection in Service

Settings Change Initialization

Settings File Received

Settings Group 1 in Service OUT 50




System Critical Error

System Event

System Non Critical Error

Three Phase Open Command

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Commissioning

SECTION 12. DISTANCE RELAY COMMISSIONING Please review the following important information on the GARD Distance Relay Module before beginning the commissioning procedure.

• If your Distance Relay module was purchased as part of the GARD8000 system, the Distance Relay Protection Scheme logic consisting of edn, text files and Distance Relay settings were already loaded into the GARD8000 system. However, if the Distance Relay module was added into an existing GARD8000 system, new Distance Relay Logic and settings have to be uploaded into the GARD8000. All the necessary steps to upload a new Distance Relay logic are covered at the end of this Commissioning Procedure. (See Section 4.6.4.13 and 4.6.4.14).

• Due to the large amount of Distance Relay settings and features, it is recommended that the

user obtain a copy of the GARD System Instruction Manual. A hard copy and/or a CD of the Instruction Manual is provided with the purchased system. A software version (PDF) of the Manual can be downloaded from RFL website at: (http://www.rflelect.com/operatingmanual.html) or from the GARD8000 System chassis. Note that because of file size restrictions the manual downloaded from the GARD chassis has all graphics removed. (Once the GARD is powered up; from the Home web page click on “Settings,” select “File Operations,” select “Save File to PC," select “Gard System Manual PDF.”

• The GARD 8000 Emulator software can be used ahead of an actual commissioning in an off-

line mode to program the Distance Relay or GARD8000 system settings and save them to a file. Later, during the commissioning process this file can be uploaded to the GARD 8000 system. The GARD 8000 Emulator software can be downloaded from RFL website at: http://www.rflelect.com/GARD%208000.html

• The Distance Relay can be programmed with four independent groups of settings. Unless

specifically requested, the settings in Group 4 are programmed with the factory default settings. These settings can be used during the initial commissioning/startup of the GARD8000 Distance Relay system. Proceed to the next page for a step for step Distance Relay Commissioning procedure.

12.1 EQUIPMENT REQUIREMENTS The following equipment is required to perform the commissioning procedure:

1. Power System Simulator

2. Test Connectors

3. Ohmmeter or contact opening/closing sensing device

4. PC with Ethernet Port and Internet Explorer

5. Ethernet Cable (straight-thru)

6. Reference Control Drawings for all Hardware and Logic

GARD 8000 Distance Relay RFL Electronics Inc. March 1, 2009 12-1 973.334.3100

http://www.rflelect.com/operatingmanual.html

http://www.rflelect.com/GARD%208000.html

Commissioning


12.2 POWER CONNECTIONS

1. Before powering up the GARD 8000 chassis (new GARD system) remove the front panel, re-seat the front functional modules, re-seat the Main Power Supply or Supplies, ensure that the power supply or supplies match the power requirements.

Note: If the Distance Relay is being added to an existing system it can be inserted under power. Insert the Rear I/O Module before inserting the Front Distance Relay Module. For removal under power extract the Rear I/O Module before removing the Distance Relay Module.

2. The Main power supply of the GARD 8000 is labeled on the rear terminal block as Power Supply #1. If the GARD 8000 relay was configured with the Main and Redundant Power Supplies connect the power source on the rear terminal block labeled for Power Supply #1 and Power Supply #2.

3. Locate the rear panel power switch, move the switch to the ‘OFF’ position before connecting power.

4. Connect a station ground to the GND terminal on the Power Supply I/O module and connect voltage source to the terminals marked + and -. Polarity is unimportant.

5. Turn on the voltage source connected to the GARD 8000 power supply inputs and move the power switch to the ‘ON’ position.

12.3 BOOT-UP PROGRESS 1. The Boot-Up progress of the GARD 8000 can be monitored through LED #1 located on the

Controller Module The front panel needs to be removed to observe the Status LED’s. 2. A complete Boot-up of the GARD 8000 is indicated by the LED #1 lighting Green. For more

information about other status LED’s on the Controller Module please refer to Section 6 of the GARD System Manual.

Enable/Disable Switch

Figure 12-1. GARD 8000 Controller Module (Commissioning, Distance Relay)

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Commissioning


12.4 ETHERNET CONNECTION

1. Connect an Ethernet cable from a PC to the front Ethernet port on the GARD Display module. 2. Set the IP address for the PC to 192.168.1.x (x = 6 to 254) 3. Open the web browser (Internet Explorer version 6 or greater) 4. Enter the GARD front port address into the address bar of the browser (192.168.1.1). 5. Login to the GARD by typing the User Name: Admin and User Password: Admin. 6. Set the rear port IP address (if desired) from the pull-down menu Settings > Chassis

Configuration > Controller and set the system time through the “Systems Labels and Time” web page.

12.5 LOGIC/SOFTWARE VERIFICATION 1. At the “Home” page click on “Help” and select “About.” 2. Verify current Logic and Systems Software revisions. 3. Confirm the programmed Logic file with the Logic name provided in the Reference Control Drawings. 4. Get familiar with the design of the Distance Relay Logic Scheme. The logic inside the Distance

Block on the Logic Schematic is fixed as delivered from the factory, but can be custom ordered for a specific application.

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Commissioning


12.6 DISTANCE RELAY WIRING VERIFICATION 1. Verify the Voltage and Current connections on the Distance Relay Input/Output module. The

I/O terminals for the Distance Relay are fixed, and should be wired in accordance with the AC schematic shown below. The Distance Relay I/O module must be installed in the same physical slot as the Distance Relay Module.

2

3

4

5

6

7

8

9

GARD 8000

A

B

C

Slot 3

VA

VB

VC

VA

VB

VC

VN

V synccheck

13

14

16

17

19

20

IA

IB

IC

I sensitive neutralor currentpolarizing

I neutral fromparallel line forfault locator

10

11

22

23

IA

IB

IC

52

IN

Figure 12-2. AC Schematic for GARD Distance Protection

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Commissioning


12346 58910 714 13 12 1118 17 16 1521 20 19222324

ChassisGND

VA+VC+VC- VA-VB+VB-Chassis

GND

IA+IA-IB+Chassis

GND

IB-IC+Chassis

GND

IC-Chassis

GNDChassis

GND

Rear Slot 3

IPol+VSyn-

VSyn+

IPol-IPN- IPN+

Figure 12-3. Distance Relay I/O connections (Commissioning)

12.7 DISTANCE RELAY CONFIGURATION SETTINGS VERIFICATION 1. Click on “Settings,” and select “Chassis Configuration” 2. At the “Chassis Configuration” page click on “Distance Relay” 3. At the “Distance Protection” web page, (see below) confirm all of the Distance Relay settings

related to a specific application. 4. Ensure the Distance Settings programmed at the Factory match the required settings.

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Commissioning


12.8 NOMINAL VOLTAGE AND CURRENT VERIFICATION • If the wiring from the Current Transformer and Potential Transformer was already completed,

please follow the instructions below to verify the Voltage and Current values. 1. Click on the “Home” page in order to display the “Chassis Configuration Status” web page. 2. At the “Chassis Configuration Status” web page click on the “Distance Relay” module. 3. At the “Distance Protection” web page click on “Distance Measured Values” see the following

page.

4. Verify the Distance Measured Values. 5. After verifying the “Distance Measured Values” click on “Metering Values” to obtain the

Nominal Voltage and Current measured values of the external equipment.

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Commissioning


6. All Voltage and Current levels should be zero if the external current and voltage sources are not applied.

7. Connect a Power System Simulator, apply current or voltage, refresh the screen and verify the metering values.

12.9 INPUT/OUTPUT MAPPING VERIFICATION

• The physical Inputs and Outputs are mapped on the “System Logic Configuration” web page. Any available hardware input or output can be freely assigned to any logical input or output that is available in the Input or Output mapping block (please use the GARD logic drawing as a reference). Verify which current logical inputs and outputs are mapped to the hardware inputs and outputs using the web pages. Additional logical inputs or outputs could be mapped in the Input Mapping and Output Mapping Logic blocks located in the Distance Relay Logic Design.

1. At the “Home” web page click on “Settings” and select “System Logic Configuration.” 2. Click on “Input Mapping” and verify all Input Mapping.

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Commissioning


3. Click on “Output Mapping” and verify all Output Mapping.

4. Mapping changes can be made using the same web pages. (Any changes on the Input and Output mapping web pages must be first saved and then reloaded to the GARD chassis).

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Commissioning


12.10 LED LOGIC ASSIGNMENTS VERIFICATION

1. Before proceeding with the functional testing, verify the LED Logic Assignments in order to determine which LED’s located on the Display/TPS module are associated with the Distance Relay functions.

2. At the “Home” web page click on “Settings,” from the drop-down menu select “System Labels and Triggers” and then select “LED Logic Assignments”

3. Confirm correct LED assignments.

Note: Not all labels are shown

12.11 SYSTEM CONFIGURATION VERIFICATION

1. From the “Home” web page click on the “Controller” module. 2. Verify “System Labels,” Active Power Supply or Supplies Voltages, Rear Port IP Address,

Network Mask, and System Time and Date (the IRIG-B if connected will overwrite the System Time and Date settings).

3. Modify the programmable settings, if needed.

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Commissioning


12.12 DISTANCE RELAY FUNCTIONAL TESTING

The GARD8000 Distance Relay can be programmed with 4 Groups of settings. Each group can be set independently with custom designed settings. Unless specifically requested during an initial ordering of the equipment, Group 4 is programmed in the factory with the default settings. The Group 4 settings can be used to perform basic functional testing of the Distance Relay.

This commissioning procedure covers the following BASIC tests:

A, B, C Phase to Ground 3 Phases to Ground A to B Phase A to C Phase 3 Phase

Before proceeding with any of these tests verify the Factory Default settings for Group 4. The factory programmed Group 4 settings are accessible under “Settings,” > “Chassis Configuration,” “Distance Relay,” “General Settings” and “Active Setting Group,” select group 4 and click on “Save.”

During functional testing the Distance Relay SOE records, GARD8000 System SOE records and Distance Relay Oscillography can be retrieved for an evaluation.

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Commissioning


• To retrieve the Distance Relay SOE’s click on the “Distance Relay module” at the “Home” page and select “Distance Sequence of Events.”

• To retrieve the GARD8000 System SOE records click on “SOE” at the “Home” page and select

“System and Teleprotection.” • To retrieve the Distance Relay Oscillography records click on “Distance Relay” from the

“Home Page” and select “Receive Oscillography from Distance Relay.” Select one of the time stamped Oscillography records stored in the Distance Relay. At the “Receive File from Distance Relay” screen, download first Oscillography Data and then Oscillography Configuration since each Oscillography (COMTRADE) type record consist of two files. Both files should be saved in the same folder with the identical file names.

After the download is completed, the data files can be opened with COMTRADE compatible software used for viewing the Oscillography records. RFL provides free of charge a copy of COMTRADE compatible software that can be downloaded from the RFL website: www.rflelect.com or contact RFL Customer Service at 973-334-3100 by e-mail: [email protected]

Below are samples of Power System Simulator settings for executing basic Distance Relay tests:

Zone 1-Phase A to Neutral-80% of the Line Line Pos.Seq. Impedance Magnitude set for 1 Ohm with Zone 1-No Delay, Zone 2-250ms Delay, Zone 3-500ms Delay, Zone 4-750ms Delay.

Pre-Fault Settings Fault Settings

Source Amplitude Phase Angle

Frequency (Hz) Amplitude Phase

Angle Frequency

(Hz) VA 69.00V 0.00° 60.00 8.47V 0.00° 60.0 VB 69.00V 240.00° 60.00 69.28V 240.00° 60.0 VC 69.00V 120.00° 60.00 69.28V 120.00° 60.0 IA 0.00A 0.00° 60.00 10.00A -70.00° 60.0 IB 0.00A 0.00° 60.00 0.00A 0.00° 60.0 IC 0.00A 0.00° 60.00 0.00A 0.00° 60.0

Expected Results: Zone 1 picks-up for Phase A to Neutral Fault, other Zones restrain.

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Commissioning


Zone 2-Phase A to Neutral- 120% of the Line




Angle Frequency


Expected Results: Zone 1 restrains, Zone 2 picks up for Phase A to Neutral Fault. Zone 3-Phase A to Neutral




Angle Frequency


Expected Results: Zone 1, Zone 2, Zone 4 restrain, Zone 3 picks up for Phase A to Neutral Fault. Zone 4-Phase A to Neutral




Angle Frequency


Expected Results: Zone 1, Zone 2, Zone 3 restrain, Zone 4 picks up for Phase A to Neutral Fault.

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Commissioning


12.12.1 ADDITIONAL FUNCTIONAL TESTING Zone 1- Phase B to Neutral




Angle Frequency

(Hz) VA 69.00V 0.00° 60.00 69.00V 0.0° 60.0 VB 69.00V 240.00° 60.00 16.00V 240.0° 60.0 VC 69.00V 120.00° 60.00 69.00V 120° 60.0 IA 0.00A 0.00° 60.00 0.00A 0.00° 60.0 IB 0.00A 0.00° 60.00 18.00A 165.00° 60.0 IC 0.00A 0.00° 60.00 0.00A 0.00° 60.0

Expected Results: Zone 1 picks-up for Phase B to Neutral Fault, other Zones restrain. Zone 1- Phase C to Neutral




Angle Frequency

(Hz) VA 69.00V 0.00° 60.00 69.00V 0.00° 60.0 VB 69.00V 240.00° 60.00 69.00V 240° 60.0 VC 69.00V 120.00° 60.00 5.00V 120° 60.0 IA 0.00A 0.00° 60.00 0.00A 0.00° 60.0 IB 0.00A 0.00° 60.00 0.00A 0.00° 60.0 IC 0.00A 0.00° 60.00 10.00A 68.99° 60.0

Expected Results: Zone 1 picks-up for Phase C to Neutral Fault, other Zones restrain. Zone 1- Phase ABC (3-Phase)




Angle Frequency

(Hz) VA 69.00V 0.00° 60.00 10.00V 75.00° 60.0 VB 69.00V 240.00° 60.00 10.00V -44.00° 60.0 VC 69.00V 120.00° 60.00 10.00V 195.00° 60.0 IA 0.00A 0.00° 60.00 15.00A 0.00° 60.0 IB 0.00A 0.00° 60.00 15.00A 240.00° 60.0 IC 0.00A 0.00° 60.00 15.00A 120.00° 60.0

Expected Results: Zone 1 picks-up for 3-Phase Fault, other Zones restrain.

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Commissioning


Zone 1 Phase A-B


Source Amplitude Phase Angle Frequency Amplitude Phase

Angle Frequency

VA 69.00 0.00° 60.000 10.00 -7.11° 60.0 VB 69.00 240.00° 60.000 10.00 -22.89° 60.0 VC 69.00 120.00° 60.000 69.00 165.00° 60.0 IA 0.00 0.00° 60.000 10.000 0.00° 60.0 IB 0.00 0.00° 60.000 10.000 -180.00° 60.0 IC 0.00 0.00° 60.000 0.000 0.00° 60.0

Expected Results: Zone 1 picks-up for Phase A-B Fault, other Zones restrain Zone 1 Phase C-A



Frequency (Hz)

Amplitude Phase Angle

Frequency (Hz)

VA 69.00V 0.00° 60.00 50.00V -22.89° 60.0 VB 69.00V 240.00° 60.00 144.34V 165.00° 60.0 VC 69.00V 120.00° 60.00 50.00V -7.11° 60.0 IA 0.00A 0.00° 60.00 10.00A -180.00° 60.0 IB 0.00A 0.00° 60.00 0.00A 0.00° 60.0 IC 0.00A 0.00° 60.00 10.00A 0.00° 60.0

Expected Results: Zone 1 picks-up for Phase C-A Fault, other Zones restrain After each test, the operation of the trip outputs can be verified by monitoring the Front Panel Programmable LED’s or retrieving the System SOE records, Distance Relay SOE records and Distance Relay Oscillography records.

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Commissioning


12.12.1.1

12.12.1.2

LOADING A NEW GARD 8000 SYSTEM LOGIC (TXT FILE, EDN FILE)

1. At the “Home” Web page, click on “Settings” and select “File Operations.” 2. Click on “Send File to Gard 8000.” 3. At “Send File to Gard 8000” select “System Logic Data Base (.txt file).”

(Note: The txt file must be loaded before the edn file). 4. Click on “Browse,” locate the new txt file and then click on “Send.” 5. After uploading the txt file, follow the above steps to load the “System Logic file (.edn).” 6. Verify the Distance Relay settings. If the Distance Relay settings for a specific application were

not programmed at the factory, modify the programmable settings under “Settings,” “Chassis Configuration” “Distance Relay.”

7. Modify the Front Panel LED Logic Assignments, SOE Triggers and Labels, Logic Bit Labels, Alarm Configuration, Map the Inputs and Outputs in order to accommodate the new Distance Relay module.

LOADING A WHOLE CHASSIS CONFIGURATION

1. At the “Home” web page, click on “Settings” and select “File Operations.” 2. Click on “Send File to Gard 8000.” 3. At “Send File to Gard 8000” select “Whole Chasis Config (.zip file).” 4. Click on “Browse,” locate the zip file and then click on “Send.” 5. After a successful loading a message is displayed; power cycle the GARD8000 unit.

This ends the commissioning procedure.

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Commissioning



March 1, 2009 12-16 973.334.3100

Index

SECTION 13. INDEX

GARD 8000 Distance Relay RFL Electronics Inc. August 1, 2009 13-1 973.334.3100

B

Breaker Supervision Functions · 9-84

Breaker Failure · 9-70 Broken Conductor · 9-63

C

Chassis Distance Relay · 6-2

Close into Fault · 9-31 Commissioning · 12-1

Boot-Up · 12-2 Ethernet Connection · 12-3 Power Connections · 12-2

Complete Signal List - Distance · 11-24 Configuration · 6-1

Hardware · 6-1 Overview · 6-1

Connections · 6-4

D

DCB · 9-21 DCUB · 9-23 Description of Operation · 9-1 Digital Fault Recording · 10-12 Dircct Transfer Trip · 9-18 Directional Elements · 9-9 Directional Overcurrent Pilot Schemes · 9-61 Directional Units · 9-55

Ground · 9-58 Negative Sequence · 9-60

Distance Elements · 7-7 Downloading

Oscillographic · 10-13

E

EFFECTIVE PAGES · xii External Connections

3U · 6-2

F

Fault Detector · 9-29 Increase of Sequence Currents · 9-29

Fault Locator · 10-13 Fault Records, Web Pages · 10-8 Frequency Units · 9-68 Functional Testing · 12-10

G

General description · 2-1 General Overview · 2-1

I

Inverse Characteristic Curves · 9-40

L

List of Tables · vii Load Enchroachment · 9-33 Loading System Logic · 12-15 Loading Whole Chassis Config. · 12-15 Logic

Distance Elements · 9-12 Memory Voltage · 9-13 Open Pole · 9-30 Reclosing · 9-78 Transient Block · 9-25 Trip · 9-75 Week Infeed · 9-26

Logic Programming · 11-1 Default Input Programming · 11-2 Factory Default · 11-1 Inputs 52A or 52B · 11-1 Loading the Compiled file to the GARD · 11-20 Operands · 11-10 Outputs · 11-4 Programming a Ditital Input or Output · 11-13 Pushbutton Operation · 11-2 Saving and Compiling · 11-17 Zivercom · 11-6 Zivercom Starting · 11-6

M

Mapping Input · 6-3 Output · 6-4

Measured Values and Trip Status, Web Pages · 10-1 MHO · 9-1

N

Non Pilot and Pilot Schemes · 9-15 Stepped Distance · 9-15

Index


O

Operating Times · 4-1 Overcurrent Elements · 9-37 Overcurrent Units

Directional Control · 9-54 Overvoltage Units

Ground Overvoltage · 9-67

P

Phase Locator · 9-28 POTT · 9-19 Power Swing Block · 9-33 PUTT · 9-16

Q

Quadrilateral Characteristic · 9-6

R

Reclosing Unit · 9-76 Related Documentation · vii Remote Open Breaker · 9-35 Resistive Blinder · 9-10 REVISION RECORD · xii

S

SAFETY SUMMARY · x Schematic

Distance Protection · 6-5 Distance Relay Inputs · 6-6 Distance Relay Outputs · 6-7

Series Compensated Applications · 9-85 Setting Examples · 8-1

Stepped Distance · 8-1 CCVT · 8-2 Distance Elements, Zone 1 TO Four · 8-9 General Settings · 8-2 Line · 8-1 Line Protection · 8-3 Reach · 8-8 Secondary Values, Conversion · 8-1 Zone Supervision, Current and Misc. Current Elements ·

8-12 Settings

Breaker Failure · 7-27 Current

Misc. · 7-23 Current Elements

Directional · 7-15 Phase · 7-16

DFR · 7-30 Distance Elements

Pilot, Comms Scheme · 7-9 Swing Block and Advanced Functions · 7-11 Zone 1 to 4 · 7-7

General · 7-1 Ground Elements · 7-18 Line Protection System · 7-2 Negative Sequence Elements · 7-20 Recloser and Sync Check

Recloser · 7-24 Synch Check · 7-26

SOE Mask · 7-33 Voltage Elements · 7-28

Settings Oscillography Mask · 7-31 Snub Bus Protection · 9-62 SOE, Reports and Fault Recording, Web Pages · 10-1 SOE, Web Pages · 10-6 Specifications · 3-1 Standard and Type Tests · 5-1 Synch Check · 9-72

Pole Discordance · 9-74

T

Table of Contents · iii Table of Figures · v Thermal Image Unit · 9-63 Time Overcurrent Units · 9-37 Torque Control, Zone 2 · 9-60

V

Verification Configuration Settings · 12-5 LED Logic · 12-9 Logic Software · 12-3 Mapping · 12-7 Nominal Voltage · 12-6 System Config. · 12-9 Wiring · 12-4

Voltage Units · 9-65 Phase Overvoltage · 9-66

W

WARNING LABELS · ix WARRANTY · ii

August 1, 2009 13-2 973.334.3100

Application Notes


SECTION 14. APPLICATION NOTES This section contains application notes, which are intended to assist users in configuring their GARD Distance Relay Module. In most cases the application note would be customer specific. The following application notes are included in this section.

March 1, 2009 14-1 973.334.3100

Application Notes


March 1, 2009 14-2 973.334.3100

instruction manual gard 8000 distance relay module · 2017-05-23 · april 1, 2010 i 973.334.3100...

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