REL512 Firmware Version 1.61 Addendum (03/27/03)

Transcription

1 REL512 Firmware Version 1.61 Addendum (03/27/03) Revisions The following revisions are added to firmware V 1.60 to provide firmware V 1.61 for all applications. These revisions are to be added (inserted) to the REL512 Revision History as the first item under Main Board on page xiv. Version 1.61 (03/27/03) This version is provided for the version 1.x main board. Existing installations may be upgraded if one or more of the following revisions are desired / applicable. 1. Increased the sensitivity of the ground directional unit I0Ip. It results in faster operation of Ip polarized ground directional element. This is applicable only when the directional ground polarization is chosen V0/Ip and a polarizing current input is wired to the Ip input of the relay. 2. Implemented a plausibility check and correction of the DC reference voltage level in all analog channels. This mechanism continuously monitors the reference voltage and corrects any variations, improving the reach accuracy of the relay. 3. Added a separate change-of-voltage detector dvlop for detecting fuse failure with a higher voltage drop setting of 27V against the existing dv setting which is about 7V. This way, LOP Block will not appear for any minor system voltage dips or variations. 4. Added a delay of ½ cycle time to and Stub bus protection trip and breaker fail repeat trip in order to ensure that tripping takes place only if the corresponding binary inputs dwell above a minimum time. The former is applicable only when stub bus protection has been implemented such as for one-and-ahalf breaker sub-station with line connected VT and the latter when breaker fail protection option has been included in the relay. The only additional setting will be a new mappable signal DC Offset alarm. If desired this can be programmed to any of the programmable output relays. The firmware 1.61 works with the upgraded RELTools V3.04. Instructions: The following information complements IB V1.61, Jan 2002, to provide additional instructions to address the items above. DC reference Voltage: A mappable signal DC Offset alarm is generated when the reference voltage varies about 10% of the nominal internal electronics reference value. The protection will be taken out of service when the voltage exceeds 25% of the nominal value, which represents a failure of a component. The following text replaces the text for the menu option describing the configuration of output maps on page Add the following to the list of signals under CPU Logic signals which are mappable DC offset alarm

2 LOP Block Logic With the introduction of dvlop, the logic blocks in page 5-16 get modified as follows:

3 Breaker Failure Trip Logic With the introduction of 0.5 Cycle delays to XBFI and 86T inputs, the logic blocks in page 5-37 gets modified as follows:

4 Stub Bus Logic With the introduction of 0.5 Cycle delay to Stub bus trip logic, the logic block in page 5-26 gets modified as follows:

5 Instruction Booklet REL512 January 2002 (IB ) This Instruction Book is applicable to the REL512 Versions 1.0 to 1.6. ABB Inc. Substation Automation and Protection Division 7036 Snowdrift Road Allentown, PA USA Tel: (610) Fax: (610)

6 Table of Contents Table of Contents... ii Guide to Figures...x Guide to Tables... xii Introduction... xiii REL 512 Revision History... xiv Section 1 Product Overview Application New Protection Concepts One Cycle Operation Distance Protection Pilot Logic Overcurrent Protection & Supervision Fault Locator I/O Mapping Logic Programmable Logic Communication to the Relay Digital Fault Recorder Platform Overview Platform Components Hardware/Firmware Structure Relay Operation REL 512 Engine Control, Logic and Data Acquisition Advanced Relay Diagnostics Platform Rating and Tolerances Functional Specifications Operating Units Impedance Measuring Units Blinder Units Overcurrent Units Instantaneous (Type 50) Units Time Overcurrent (Type 51) Units Voltage Units Operating Unit Accuracy Impedance Units Instantaneous Overcurrent Units Inverse Time Overcurrent Units Voltage Units Directional Unit Sensitivity Time Delay Timers Protective Functions Basic Distance Functions Overcurrent Functions Voltage Functions Page ii Table of Contents

7 Pilot Functions Breaker Failure Functions (Optional) Settings Automation Functions Reclose Inputs and Outputs Inputs Outputs I/O Mapping and Programmable Logic Fault Information LED s Fault Location Digital Fault Recording Programmable Logic Catalog Information Section 2 Acceptance, Installation, and Maintenance Acceptance Installation External Connections AC and DC Connections I/O Connections Communication Connectors Internal Connections I/O Jumpers Binary Input Jumpers Output Relay Contact Jumpers Maintenance Section 3 Operation Communicating with the Relay Front Panel User Interface View Mode Editing Mode LED s Reset Button Computer Communication Interfaces RS232 Ports Cable Connections ASCII/English Protocol Typical Communication Program Settings Interfacing with the Relay The REL 512 Interface Menu Root Menu Monitoring Functions Password Functions Retrieve Data I/O Mapping Relay Inputs and Outputs Output Contacts Fixed (Non-Programmable) Outputs Programmable Outputs DSP Signals Table of Contents Page iii

8 Programmable CPU Logic Signals Programmable Binary Inputs Miscellaneous Functions Trip Coil Monitoring Changing the Settings from an External Switch Programmable Logic Section 4 Settings and Application Settings Notation Relay Configuration Parameter Settings Operating Element Settings Logic Operation Settings Protection I/O Mapping Relay Configuration Relay Location and Identification Instrument Transformer Connections Power System Parameters Data Display and Fault Recording Communication Front RS232 Communication Port Settings Rear RS232 Communication Port Settings Networks/SCADA Protocols Impedance Elements Zone Zone Zone Forward Pilot Zone Reverse Pilot Zone Line Characteristics Out-of-Step and Load Restriction Blinder Settings Out-of-Step System Type Load Restriction Out-of-Step Block Out-of-Step Trip Instantaneous Overcurrent Elements (Type 50) High Set Overcurrent Elements and Functions Medium Set Overcurrent Elements and Functions Low Set Overcurrent Elements and Functions Inverse Time Overcurrent Elements (Type 51) Time Overcurrent Characteristics ANSI/IEEE IEC Time Overcurrent Elements Other Overcurrent Elements and Logic Functions Voltage Elements and Logic Functions System Logic Type System Type (Pilot/Non-pilot) Step Distance (Non-pilot) Scheme Selection Pilot Scheme Selection Permissive Overreach Transfer Trip (POTT) Permissive Underreach Transfer Trip (PUTT) Directional Comparison Unblocking Page iv Table of Contents

9 Directional Comparison Blocking Pilot System Reclosing Trip Type Breaker Failure Protection Protection I/O Mapping Input Map Signals Output Map Signals Settings Tables through 4-49 Guide to Settings Tables Section 5 Measuring Elements and Operational Logic Variable Mho Impedance Characteristics The Mho Circle Memory Voltage Polarization Mimic Circuit Three-phase Unit Torque Operating Times Ground-Quadrilateral Characteristics Blinders Directional Units Phase Directional Units Ground Directional Units Negative Sequence Units Directional Unit Sensitivity Overcurrent Units Operating Units (Type 50) Operating Characteristics Inverse Time Overcurrent TD 51 Inverse Units Voltage Units Phase Undervoltage Units Ground Overvoltage Unit Phase Overvoltage Units Measuring Unit to Logic Tables through 5-13 Operational Logic High Speed DSP Logic Logic Diagrams through 5-38 CPU Logic Section 6 Testing the REL 512 Testing the REL Acceptance Test Test Equipment Front Panel and Metering Check Communication With Terminal Setting Changes I/O Checks Trip Operation Check Impedance Accuracy Check Evaluation and Performance Test Equipment Required Test Procedures Non-Pilot Performance Tests for REL Table of Contents Page v

10 Settings Changes and Observations Energization of Relay Zone 1 Logic Test Procedure for Clearing and Configuring Contact and Logic Mapping Zone 1 Test Preparation Zone 1 Test Procedure Zone 2 Logic Test Zone 2 Test Preparation Zone 2 Test Procedure Zone 3 Logic Test Zone 3 Test Preparation Zone 3 Test Procedure Pilot Zones Tests Forward Pilot Zone Test Preparation Forward Pilot Zone Test Procedure Reverse Pilot Zone Test Procedure Overcurrent Logic Tests Medium Set Ground Trip Test Preparation Test Procedure for STUB Bus Trip Test Procedure for High Set Trip Test Procedure for Time Delay Phase Overcurrent Test Procedure for Time Delay Ground Zero Sequence Overcurrent Test Procedure for Time Delay Negative Sequence Overcurrent Test Procedure for Close into Fault Trip Test Procedure for Breaker Failure Logic (Optional) Test Procedure for Loss of Potential Block Logic Test Procedure for Load Loss Trip Logic Pilot Performance Tests for REL Settings Changes and Observations Energization of Relay Pilot System Tests Procedure for Clearing and Configuring Contact and Logic Mapping Directional Comparison Blocking Test Preparation Directional Comparison Blocking Test Procedure Permissive Overreach Transfer Trip (POTT) System Test Preparation POTT System Test Procedure Permissive Underreach Transfer Trip (PUTT) System Test Preparation PUTT System Test Procedure Unblocking System Test Preparation Unblocking System Test Procedure Single Pole Trip Test Preparation Single Pole Trip Test Procedure Section 7 RELTOOLS RELWISE-Settings Editor and Advisor Introduction Instructions Editor Advisor Start Screen File Menu Editor-Advisor Editor Advisor File Screen View Configuration Catalog Number Page vi Table of Contents

11 Group Settings Edit Configuration Settings Edit Protection Logic Settings Edit Input Map Settings Edit Output Map Settings RELLOGIC-Programmable Logic Introduction File Menu Group Logic Categories Timer/Latch Unit Logic Controls Timer Control Logic Latch Control Logic Programming the Relay Developing the Program File Loading (sending file) to the Relay RELWAVE-Digital Fault Recording and Analysis Introduction Data Display Windows Analog Window Digital Window Control Panel Cursor Frame Delta Frame ZOOM Frame TASK Frame Delta Option Fault Option Marker Option Command Buttons Open IPlot V (vector) Print Copy ? (Help) Notes Exit Ohms H (harmonic analysis) The Fault Record Section 8 Reclosing Application Synchronism-Checking Logic Angular Synchronizing Characteristic Phasing Voltage Synchronizing Characteristic Breaker Monitoring Analog Inputs Functional Specifications Reclosing Synchronism Table of Contents Page vii

12 Recloser Monitoring Manual Close Binary Inputs Analog Outputs Installation and Operation Reclose Module Rating and Tolerances Control Power Requirements Operating Environment Installation Diagrams for Reclosing 2.XX External Connections Reclosing and Synchronizing Reclose Settings and Application Synchronism and Voltage Check Reclosing Reclose Reclose Reclose Reclose Manual Close Breaker Monitoring Input and Output Settings Binary Inputs Analog Outputs Settings Tables through 8-18 Operating Logic Recloing Logic Reclosing Sequence Follow Breaker Logic Synchronism and Voltage Check Logic Synchronism Check Reclose Criteria Voltage Check Reclose Criteria External Supervision Reclose Criteria Manual Close Function Breaker Monitoring Logic Acceptance and Maintenance Tests Setup Preparation for Testing the Reclosing Module Input and Output Tests Voltage Check Sync Check Breaker Control Failed Reclose Manual Close/External Supervision Drive to Lockout and Hold Cumulative Operations Alarm Test Finalization Analog Outputs Setup Testing Analog Outputs Analog Output (1) Line-to-Ground (Line) 1 f Analog Output (2) Current 1f Analog Output (3) Watts 3f Analog Output (4) Vars 3f Analog Output (5) Fault Location Page viii Table of Contents

13 Analog Output (6) Line-to-Ground Volt (Bus) 1f Analog Output (7) Synchronism Angle Analog Output (8) Slip Frequency Breaker Control Functions Setup Breaker Open Breaker Close Breaker Close with Supervision Test Finalization Maintenance Section 9 Firmware Upgrading REL 512 Firmware Upgrade Section 10 Support Documentation Application Note AN-40L-99 Overreaching of the Impedance Characteristic Using Automated Testing Application Note AN-41L-99 Fault Location and Phase Selection from the Digital Fault Recording Application Note AN-54L-00 Retrieving REL 512 Data Using Windows Hyperterminal Application Note AN-59L-00 REL 512 Setting Example for Medium and Long Lines Table of Contents Page ix

14 Guide to Figures Section 1 Product Overview Figure 1-1 Zone Phase and Ground Impedance Units Figure 1-2 Zone Impedance Unit Operating Time Figure 1-3 Communications to the Relay Figure 1-4 Digital Fault Record and Analysis Figure 1-5 REL 512 Platform Front Panel (Horizontal Mounting) Figure 1-6 Basic Relay Operation Figure 1-7 Phase Comparator Figure 1-8 Impedance Unit Operating Time Figure 1-9 Instantaneous Overcurrent Unit Operating Time Section 2 Acceptance, Installation, and Maintenance Figure 2-1 Top View Figure 2-2 Front View Figure 2-3 Rear View Figure 2-4 Terminal Blocks TB1 and TB Figure 2-5 Terminal Blocks TB3, TB4, and TB Figure 2-6 Typical REL 512 DCB Pilot Scheme Connection to TC-10B, Part Figure 2-7 Typical REL 512 DCB Pilot Scheme Connection to TC-10B, Part Section 3 Operation Figure 3-1 Front LCD User Interface Figure 3-2 Trip Coil Monitoring Scheme Figure 3-3 ASCII Menu Breaker Control Section 4 Settings and Application Figure 4-1 Impedance Measuring Units Figure 4-2 Out-of-Step (Power Swing) Figure 4-3 Load Restriction Figure 4-4 Inverse Time Overcurrent Characteristics Section 5 Measuring Elements and Operational Logic Figure 5-1 Mho Characteristic Test Figure 5-2 Memory Circuit and Response Figure 5-3 Operating Time for SIR of 1 to Figure 5-4 Mho-Quadrilateral Composite Characteristic Figure 5-5 Blinder Lenticular Characteristic Figure 5-6 A Mho Characteristic Supervised by the Blinder Characteristic Figure 5-7 Three Phase Directional Units Figure 5-8a Zero Sequence Voltage Polarization Figure 5-8b Transformer Zero Sequence Current Polarization Figure 5-9 Negative Sequence Directional Unit Figure 5-10 Sensitivity of Ground Directional Unit Figure 5-11 Typical Operating Characteristics for Instantaneous Overcurrent Units Figure 5-12 CO-8 Emulation Figure 5-13 Operating Characteristics of the Phase Undervoltage Units Figure 5-14 Operating Characteristics of the Ground Overvoltage Unit Figure 5-15 Logic Legend Logic Diagrams through 5-38 Page x Table of Figures

15 Section 8 Reclosing Figure 8-1 Angular Synchronizing Characteristic Figure 8-2 Phasing Voltage Synchronizing Characteristic Figure 8-3 System AC Voltage Phase-to-Ground Connections Figure 8-4 System AC AC Phase-to-Phase Connections Figure 8-5 Reclosing Sequence Logic Diagram Figure 8-6 Reclose Supervision Logic Diagram Figure 8-7 Manual Close Logic Diagram Figure 8-8 Breaker Monitoring Logic Diagram Table of Figures Page xi

16 Guide to Tables Section 1 Product Overview Table 1-1 Analog Input Circuits Table 1-2 Binary (Voltage) Input Circuits Table 1-3 Binary (Contact) Output Circuits Table 1-4 Control Power Requirements Table 1-5 Operating Environment Table 1-6 Metering Accuracy Table 1-7 Dimensions and Weight Table 1-8 Directional Unit Sensitivity Section 2 Acceptance, Installation, and Maintenance Table 2-1 I/O Connection Table Section 3 Operation Table 3-1 LED Functions Table 3-2 Fixed Outputs Table 3-3 Trip Coil Monitoring Connections Table 3-4 External Switch Operation Section 4 Settings and Application Table 4-1 Type CO Induction Relay Family Models Settings Tables through 4-49 Section 5 Measuring Elements and Operational Logic Measuring Unit to Logic Tables through 5-13 Section 6 Testing REL 512 Table 6-1 Fault Table Section 7 Support Software Table 7-1a Programmable Signals Table 7-1b Programmable Signals (continued) Section 8 Reclosing Table 8-1 Analog Input Circuits Table 8-2 Binary (Voltage) Input Circuits Table 8-3 Binary (Contact) Output Circuits Table 8-4 I/O Connections Settings Tables through 8-18 Table 8-5 Reclosing Sequence Table 8-6 Rear Connector Assignments (Reclosing Option Only) Table 8-7 Analog Output Functions Page xii Table of Tables

17 Introduction ABB REL 512 Line Protection and Breaker Control Terminal This instruction book applies to the REL 512 with the Version 1.x Main Board hardware. Version 1.x has not been shipped since the second quarter of This manual should not be used totest the REL 512 with V2.x Main Board hardware. Refer to IB for testing V2.x. Highlights The highlights of the REL 512 are: Less than one cycle trip time. Extremely reliable operating elements that allow zone-1 settings to 95% of the line. Comprehensive DFR capabilities and fault analysis program. Programmable logic with 1/4 cycle operating resolution. Easy to learn and use communication interface. Modbus Plus or DNP 3.0 network communications for Substation Automation. Comprehensive support software and documentation. This Manual This manual addresses the product application, specifications, platform overview and catalog information. It also provides basic instructions for installation, operation. It is expected that you have experience operating computer operated test sets and testing microprocessor based relays. Section 1 provides a product overview to familiarize the reader with the basic product application, relay features, and functional specifications. Information to select the proper relay catalog (style) number is also provided. Section 2 provides information to accept, install and maintain the REL512. This includes dimensional drawings, I/O terminations and typical scheme drawings to assist in system design. Section 3 covers the REL512 operations. This includes communicating with the relay through its front panel UI and computer (ASCII/RS232) interface to setup the relay for operation. The appropriate communication cables are also defined. Section 4 provides complete settings and application information. Section 5 discusses the measrung units and operational logic. The operational characteristics of each measuring unit...impedance, overcurrent, undervoltage, etc., are discussed. Complete relay logic is also provided. Section 6 provides procedures and information for testing the relay. Section 7 provides instructions for using REL512 s support software. Section 8 provides complete instructions for the optional reclosing function of the relay. Section 9 provides instruction on upgrading the relay s firmware. Section 10 provides Application Notes relevant to the REL 512 including a very comprehensive settings example. Introduction Page xiii

18 REL 512 Revision History There are four boards (hardware modules) that are independently programmed and are periodically provided with new firmware version releases. These boards are: Main Board that provides the protection functions, Reclosing Board that provides reclosing and voltage supervision for reclosing, DNP 3.0 Network Interface Board that provides an interface to SCADA or substation automation utilizing the DNP 3.0 protocol, and Modbus Plus Network Interface Board that provides an interface to SCADA or substation automation utilizing the Modbus Plus protocol. RELTools support software is also periodically upgraded to meet the requirements of new firmware releases. Correct coordination of the different firmware and support software is essential to assure proper operation of the REL 512 and RELTools. The following table defines the firmware and software version requirements for different Main Board firmware version releases. V1.xx Compatible Firmware and Software Releases Main Board CPU Reclosing Board 1618C07G01 Reclosing Board 1919C38G01 DNP 3.0 Board Modbus Plus Board RELTOOLS (1) S ettings Database A A Upgrade to 1.6 recommended. Notes: 1. Use the listed or more recent software release (higher version #). Following is a history of REL 512 firmware and RELTools support software version releases. Main Board Version 1.6 (01/31/02) This version is provided for the version 1.x main board. The 1.x main board is no longer being manufacturered having been upgrade in hardware to accomodate V2.x functions. V1.6 can only be used to upgrade installed units with a version 1.x main board. Follow are changes provided in V1.6 from V Improved password security with a 5 minutetimeout and reverting to main menu. 2. Improved the blocking carrier start timefor DCB pilot schemes to 10 ms maximum with standard contact outputs and to 4ms maximum with the optional high-speed output board. Page xiv Revision History

19 3. Changed the Set Relay Default Settings procedure to avoid accidental resetting to default settings. 4. Corrected breaker position and trip circuit monitoring LED operations. 5. Added the ability to trigger a fault record from the ASCII terminal interface. 6. Added LOP set and recrovery in the fault summary record and the ability to trigger a fault record. 7. When OS TIME 2 of the Out-of-step Trip logic (5-23) was set to minimum value of.02 and OST WAY IN/OUT was set to WAY OUT, the signal OUT OF STEP TRIP asserted. The OS Timer #2 was fixed to correct this issue. 8. Modified logic module by adding the signal PILOT SUPV to the input of the MEDIUM SET GROUND TRIP AND gate. This will block the assertion of MEDIUM SET GROUND TRIP if the system is set to PILOT SYSTEM and the pilot system is disabled by the de-assertion of 85C0 (pilot on/off switch). 9. Corrected the TRIP BLOCK function that was implemented in firmware version This involved modification to the DSP and CPU Trip Seal logic to prevent trip sealing during the period the operation of the output contacts are blocked. Version 1.58 (03/24/00) This version is provided to support existing product installations. It will be discontinued on new products manufactured with the Version 2.x main board. 1. A two cycle dropout (off-delay) time was added to Zone-2, Zone-3, forward pilot and reverse pilot trip timers to prevent dropout during evolving fault transients. 2. A 12-cycle dropout timer was added to the HSRI and TDRI reclose initiate signals to insure that external reclosers can sense the reclose initiate output. 3. Implemented trip blocking such that fixed TRIP units and all except 3 physical outputs (OUT2, OUT3 and OUT4) are blocked when TRIP BLOCK programmable input is asserted. Version 1.57 (11/03/99) 1. A DNP 3.0 Level 2 implementation was added for SCADA and substation automation network communications. 2. The main board software was modified so that only one software version is required to interface with any reclosing board. Version 1.25 (9/27/99) 1. Improved accuracy of fault location and faulted phase selection reported on the LED s, LCD user interface and DFR record for time delayed tripping longer than 14 cycles. 2. Modified the loss of potential logic (page XX below) to include the signal HS LOP BLOCK SET. HS LOP BLOCK SET appears in programmable (mapped) output signals, RELWISE and RELLOGIC software instead of LOSS OF POT BLOCK DIST. Previous settings and programmable logic files opened with the 1.25 software versions will convert from LOSS OF POT BLOCK DIST to HS LOP BLOCK SET. 3. Added logic that indicates open breaker with the 52a contact. Refer to logic drawing module The BREAKER OPEN logic is asserted by either BREAKER 1(or 2) OPEN 52b or NOT Revision History Page xv

20 BREAKER 1(or 2) CLOSED 52a. If BREAKER 1(or 2) CLOSED 52a is not mapped to an a binary input it will be set to a logic 1 value. 4. Added 52a-closed breaker logic to the breaker failure logic. Refer to logic drawing module The high speed and time delay reclose selectivity was improved. The settings Z1 TD FAULTS, PS TD FAULTS and HS 50 TD FAULTS were added. These settings enable time delayed reclosing for fault types not selected for high speed reclosing with the Z1 (PS or HS 50) RI FAULT TYPE setting. Version 1.55 (9/27/99) Includes all V1.25 modifications and new software to accommodate new recloser board with analog outputs and 50 Hz operation. Version 1.24 (7/24/99) 1. Improved DFR to record power swings. 2. Added the capability to record a DFR record via binary (voltage) input. (XDFR) 3. Added the ability to clear the programmable logic output contact control via the ASCII/RS232 interface. 4. Added the ability to provide 6 trip output contacts for three pole tripping via setting control. 5. Extended the K0 ANGLE setting range for all impedance zones from 40 to 40 to 120 to Fixed the relay to automatically reboot after editing configuration settings. 7. Fixed an error in the ASCII display for metering of primary quantities. The display should read the transformer (CT or VT) ratio times the applied current or voltage when the setting UNITS PRI/SEC is selected as PRIMARY. 8. Improved the LN R PU and LN X PU resolution from 2 to 4 places Improved transient block logic timing resolution from 1.25 cycle to 0.25 cycle to speed up dropout time to improve coordination. 10. Improved 2PHG FAULT logic by adding Zone-3 phase-to-ground elements and a dropout timer. Version 1.54 (7/24/99) Includes all V1.24 modifications and new software to accommodate new recloser board with analog outputs and 50 Hz operation. Version 1.23 (3/11/99) 1. Additional LOP logic added to latch LOP and block operation for all conditions. 2. Xmodem header files corrected to facilitate new settings. 3. Expanded firmware to 4 variations to include 60/50 Hz and 5/1 amp ct inputs. 4. Corrected UI display of low value currents to match ASCII/RS232 metered values. 5. Modified TDRI to operate for all faults only. 6. Increased BF control timer maximum settting form 0.5 sec to 2.0 sec. Note: This release does not support reclosing for 50 Hz. Page xvi

21 Version 1.21 (10/26/98) 1. Fixed an error that recorded an extra record of fault data. 2. Fixed Breaker Failure Initiate (contact 10), Time Delay Reclose Initiate (contact 11) and High Speed Reclose Initiate (contact 12) to not operate if SPT BKR2 OUT is set to ENABLE. 3. Fix the mis-spelling of success in file transfer completions. 4. Remove from TTY PUTT Weakfeed menu not required. 5. Reduce watchdog time for CPU lock-up reboot from 7 minutes to 1 minute. Version 1.20(8/26/98) 1. Quadrilateral units for Zone-1 ground were added. 2. Modbus+ Phase 1, 6X and Global registers were added. 3. DNP 3.0 Phase 1 was added. 4. Relay Settings upload checks for Version Control with RELTools were added. 5. Logic Settings upload checks for Version Control with RELTools were added. 6. Factory Default Settings Warning message appears when unit is reprogram was added. 7. Main Board firmware supporting Reclosing firmware Version 1.1 was added. 8. Manual Breaker Open/Close and Supervision though TTY were added. 9. Fixes to be 100% Compatible with HyperTerminalä were added. 10. Maximium value setting for Z1_PH_REACH, Z1_GND_REACH, Z2_PH_REACH, Z2_GND_REACH, Z3_PH_REACH, Z3_GND_REACH, FWP_PH_REACH, FWP_GND_REACH, RVP_PH_REACH, RVP_GND_REACH were changed from 50 to 36 Ohms. 11. Product information display screen updated to support new hardware options. Version 1.10(4/24/98) 1. Main Board firmware supporting Reclosing firmware Version 1.0 was added. 2. Single Pole additional trips were added using relay outputs 10, 11, and Unit style number and serial number was added to product information display. Version 1.01 (3/27/98) 1. Single pole trip logic implemented 2. Unblocking logic was updated. 3. Inverse-time overcurrent (51N) unit logic was modified. 4. LED and UI Fault Data Display was updated. Version 1.00 (11/13/97) Initial release. Page xvii

22 Reclosing Board Version 1 This is the original reclosing board design and does not include analog outputs for SCADA. Reclosing Board Version 2 Version 2.0 (09/27/99) 1. New reclosing board design that includes analog outputs for SCADA. (Version 1 reclosing board is discontinued.) Differences in the Version 1.x and 2.x Main [ and Analog] Board Version 2.x main and analog boards are currently being manufactured and shipped. Version 1.x hardware is no longer available. Version 2.x firmware cannot be used to upgrade installed units with a Version 1.x main board and visa-versa. Existing 1.x relays, however, may be upgraded with the V2.xx hardware. The upgraded hardware includes: 1. Provided the capability to accept modulated and demodulated IRIG-B signals as input to the REL 512. A processor was added to analog board to process IRIG-B signal and interface with main board. [The demodulated function is not enabled for the 1.xx chasis unless the analog board is also changed.] (Main and/or Analog Boards) 2. Jumper selectable binary voltage input ratings of 24V, 48V, 120V and 250Vdc was provided. The inputs on previous versions are the same as the power rating. (Main Board) 3. Upgrade MC68360 Microprocessor from 25 MHz to 33 MHz. Upgrade hardware and software to accommodate a 33 MHz instead of the present 25 MHz. (Main Board) 4. Provided battery back up of the present RAM so that the data remains intact in spite of cycling power or power failure. (Main Board) 5. Removed the PCMCIA card reader. [ A 1.xx board can easily be recognized as it has a PCMCIA card reader (slot) on the right front.] (Main Board) Page xviii

23 Product Overview Application ABB REL 512 Line Protection and Breaker Control Terminal The REL 512 relay system is an integrated numerical transmission line impedance protection system and circuit breaker control terminal. It offers new protection concepts delivering true one cycle tripping, the most advanced functions, and flexibility available to meet transmission line distance protection application requirements for both pilot and non-pilot. The REL 512 also includes options for automatic reclosing and breaker failure protection. The protection system is further enhanced with programmable I/O and logic, which can be set for local user functions, or monitored and controlled by your SCADA or automation system. Also, advanced patented self-testing techniques eliminate routine maintenance requirements. Concepts introduced by the REL 512 opens the door to more creative approaches for addressing protection and control needs. New Protection Concepts The REL 512 utilizes a combination of time and frequency domain algorithms, and multiple microprocessors. This provides comprehensive high-performance protection and control with one cycle operating speed and high reach accuracy. Overreach errors due to CCVT subsidence and asymmetrical fault current are eliminated. The pilot zones and Zone 1 elements, and all the elements which supervise them, are time-domain based algorithms. These follow closely the dynamic operation of the power system, responding rapidly to maintain stability during system disturbances. Some backup and support functions are handled in the frequency domain using conventional Fourier notch filter methods. One Cycle Operation Figure 1-1. Zone Phase and Ground Impedance Units High-energy faults cause fast tripping while the response is slower for low-energy or zone-boundary faults. The unit provides reliable one cycle operation for Zone 1, and pilot faults within 80% of the zone reach setting. Transient overreach of the distance elements due to asymmetrical fault current and CCVT voltage do not exist due to the adaptive nature of the inverse characteristics. Product Overview 1-1

24 The operating times determined in the above curves are based on the ratio of the system equivalent source impedance to the relay setting. This is referred to as SIR and curves are shown for values of SIR from 1 to 20. These tests were made using the high speed outputs. High energy faults with a low SIR will operate in the range of 0.5 to 1.0 cycle for more than 90% of the line. IEEE Standard C , IEEE Guide for Protective Relay Applications to Transmission Lines, defines line lengths based on SIR and recommends applications. A line is defined as long if the SIR is less than 0.5, medium if the SIR is greater than 0.5 and less than 4.0, and short if the SIR is greater than 4.0. Pilot (communication assisted) schemes, such as directional comparison, current differential or phase comparison, are recommended if the SIR is greater than 4.0. For short lines, the forward pilot impedance units permits reach settings independent of zone-2 and based on SIR to insure adequate operating speed. Distance Protection The non-pilot protection function of the REL 512 is a full distance scheme with three phase and ground quadrature polarized impedance measuring zones having variable (expandable) mho characteristics. Additional forward and reverse phase and ground measuring zones are provided for pilot or other user applications, giving a total of 5 zones. Pilot Logic Figure 1-2. Zone Impedance Unit Operating Time The REL 512 uses a comprehensive, modularized, finely tuned pilot logic scheme based on years of application experience with microprocessor based distance protection. Separate forward and reverse phase and ground pilot zones are provided. Pilot options include Blocking, Unblocking, POTT and PUTT. The logic includes two- or three-terminal line protection, transient blocking, weak feed and echo keying. High-speed carrier starting and a blocking coordination timer are provided for the blocking system to insure coordination with existing remote terminals. Overcurrent Protection & Supervision Overcurrent protection includes phase, ground and negative-sequence inverse-time functions which can be controlled with directional or zone-2 elements. All inverse time overcurrent functions offer choice of instantaneous or time-delayed reset. Overcurrent supervision of distance units provides 1-2 Product Overview

25 secure operation for loss of potential conditions, during 3 phase faults, and bus-transfer operations. A negative-sequence fault detector is provided for greater sensitivity to multiphase faults. Fault Locator The REL 512 utilizes a highly accurate fault location algorithm with fault resistance and load flow compensation. I/O Mapping Logic Forty-four binary signals are available that can be mapped to any of 12 output contacts. This allows the user to use REL 512 operating elements or logic signals to control output contacts for alarms, trips, triggering or control of external devices. Programmable Logic Sixty-four binary signals can be combined using AND and OR gated, negation, on/off delay timers and flip-flops mapped to any of 8 output contacts. This allows the user to use REL 512 operating elements or logic signals to control output contacts for alarms, trips, triggering, or control of external devices. Communication to the Relay The REL 512 has multiple communication styles to meet the needs of today s communication and automation requirements. Front and rear communications ports are available for local and remote computer access. Interactive access or file transfers can be provided with industry communications software such as Procomm â, Crosstalk â, or Windows â HyperTerminal. In addition, DNP 3.0 and Modbus Plus communications are available to meet substation automation and SCADA requirements. Figure 1-3. Communications to the Relay The front panel User Interface communications includes a 4 x 16 character backlit LCD.with multifunction keypad, plus 12 LED s for status and target indication, and a reset push-button. Digital Fault Recorder Data on the most recent 15 faults are time-tagged and stored in digital fault records. Each fault record provides detailed data for operation analysis. This includes voltage and current analog quantities, measuring unit status (on/off), I/O and key digital logic signals. Each record is 16 cycles long with a sampling frequency of 1200 Hz (20 samples per cycle) for 60 Hz applications and 1000 Hz for 50 Hz applications. This includes 2 cycles of prefault data and 14 cycles of post fault data. System events lasting longer than 14 cycles will produce multiple records to capture the entire event. The records are coordinated to within 1 ms resolution. Reference Section 7 RELTOOLS Support Software for more detailed information. Product Overview 1-3

26 165 Digital signals in scrolling window Figure 1-4. Digital Fault Record and Analysis 1-4 Product Overview

27 Platform Overview Platform Components The relay platform is suitable for mounting horizontally in a 3 RU high space on a standard 19-inch wide rack, or vertically in an FT-42 panel cutout. Figure 1-5. REL 512 Platform Front Panel (Horizontal Mounting) The platform outer chassis consists of: rear mounted terminal blocks for analog (instrument transformer) inputs, binary (dc voltage) inputs, and binary (contact) outputs; rear mounted communication interfaces and a time synchronization IRIG-B input; a front panel with a DB9/RS232 communication interface, a local user interface (UI) for metering, access to fault information and settings editing, LED s for instant visual relay operational status, and a recessed LED reset button. The front panel is released with two thumb screws and removable to allow access to the internal components. The main board, and optional expansion and communication boards are easily removed and reinstall. Hardware/Firmware Structure Relay Operation The following describes the basic relay operation. The basic hardware consists of: Analog input transformers for analog input signals A front end filter, multiplexer and A/D converter of those input signals One digital signal processors (DSP) for high speed measuring unit and logic operation One CPU processor for DSP signal buffering, logic analysis and control, and communications Status Inputs for logic operations Output contacts for control of external devices NOVRAM (nonvolatile memory) for storage of relay settings and fault records Communication interfaces Product Overview 1-5

28 Figure 1-6. Basic Relay Operation REL 512 Engine The REL 512 engine consists primarily of the analog inputs, front end filtering, multiplexing and A/D processing, and digital signal processing (DSP) based on relay operating element comparator equations with outputs going into a logic buffer for protection and programmable logic analysis. The DSP elements are the heart of the relay operation, and it is their energy dependent equation performance that provides both operating speed and accuracy. A relay element operation is based on the phase comparison of a restraining phasor and an operating phasor. These are derived from the analog inputs. When the operating phasor, S1 (see Figure 1-7) leads the restraining phasor, S2, the relay element will operate providing a logical 1 output. When S1 lags S2 the relay element will not operate and has a logical 0 output. When S1 leads or lags S2 by 90, maximum operating energy, and speed, is delivered in either the operating or restraining direction. Relay analog input quantities and threshold settings control the operation. Figure 1-7. Phase Comparator 1-6 Product Overview

29 Control, Logic and Data Acquisition Data are provided to the logic with each sample from the DSP relay measuring units. The output status of each relay measuring unit in the DSP is input to the logic buffer to await logic processing. The buffer is updated every sample. However, every logic function is not processed at every sample. Logic functions are performed on a defined priority schedule, and will read the continuously updated buffer as required. The relay protection logic requires no special programming to accomplish the protection functions of the relay. This logic is controlled by settings to enable and define the operating characteristics of the measuring units and logic functions. User programmable logic has access to selected relay operating element and logic signals, and input and output relays. Using the programmable logic, the user can perform a large number of auxiliary functions such as contact multiplication, special timers, and etc. The CPU processor also provides integration and control of the operator s control interface, communication interfaces, binary I/O, data storage, flash memory, communication to the DSP, and advanced diagnostics. Advanced Relay Diagnostics Advanced relay diagnostics eliminates the need for extensive installation evaluation testing and scheduled periodic maintenance. The concept of self-diagnostics on the REL 512 is to perform a tests on individual components at programming time, boot and in operation. Once the REL 512 boots, a set of checks are done continuously to ensure integrity of software and hardware. The diagnostics provide a means of detecting abnormalities which could lead to unpredictable operations. At boot, the RAM on the main, communications and reclosing boards is tested. If the test returns an okay, the unit boots the code from the flash. Once the system is up and running, the software does a detailed RAM check every 2 seconds which includes problems, software overruns (pointer and code) and memory leaks. The unit marks a failure if the RAM checks fail. The NOVRAM and EERPOM is tested at boot for addressing problems. Once the system boots, a CRC is maintained for logical grouping of NOVRAM or EEPROM values. These CRC s get updated every time an entry in the specific group changes. The CRC is monitored in a background process and the unit marks a failure if the CRC fails. The CPU actually boots and loads the code into the DSP s internal RAM. The DSP performs an internal test and does not boot if it sees a problem. The Main CPU reports a failure if the DSP does not boot. The CPU actually times the sample responses sent back from the DSP. If the timing is out of range, the REL 512 indicates a problem. When the firmware is downloaded to the flash, the download mechanism automatically does a checksum on the Flash device. Thus the flash device is validated at download time. A separate watchdog module inside the MC68360 runs in parallel with the CPU core. The CPU core has to refresh the watchdog timer within a pre-specified time. This will ensure detection of some kinds of hardware problem or conditions of runaway software. On the REL 512, the watchdog has a 8 second time-out, if the unit hangs for 8 seconds the watchdog will clear and reboot the REL 512. This cycle will continue if there s something wrong with the hardware that can t be detected by other means. The outcome of any problem detected is that the system will lock down, clear it s outputs, and hang (not reboot). The unit will also send to the TTY connected to the front port a message indicating the error and some diagnostics details. The relay is also provided with a comprehensive set of diagnostic tools capable of testing the relay hardware operation including input status points, output relays, and LED s Product Overview 1-7

30 Platform Rating and Tolerances Table 1-1. Analog Input Circuits Input Rating 5.0 A Rating 16 A continuious, 450 A for 1 second 1.0 A Rating 3 A continuious, 100 A for 1 second CT Input Burden Voltage Rating (69/120 V Wye) VT Input Burden Frequency Less than A 160 V continuious, 480 V for 10 seconds Less than 0.2 rated voltage 50 or 60 Hz Table 1-2. Binary (Voltage) Input Circuits Input Burden 24 V dc Less than 0.16 VA 48 V dc Less than 0.16 VA NOTE: The optically isolated binary input dc voltage rating is the same as the control power (power supply) voltage on the Version 1.X platform. The binary input dc voltage rating is jumper selectable on Version 2.X platforms. 125 V dc Less than 0.44 VA 250 V dc Less than 0.44 VA Table 1-3. Binary (Contact) Output Circuits Circuit Voltage Trip Rating Continuious Rating Circuit Break Rating Resistive / Inductive V dc 30 A 8 A 50 W / 15 VA 120 V ac 30 A 8 A 50 W / 15 VA Table 1-4. Control Power Requirements Control Voltage Amps (Burden) Operating Voltage Range 48 V dc to 58 V dc V dc 0.17 to to 300 V dc 120 Vac to 132 V ac 1-8 Product Overview

31 Table 1-5. Operating Environment Parameter Value ANSI IEC Operating Temperature C to 70 0 C C Storage Temperatute C to 80 0 C C Humidity Up to 95% without internal condensation C Insulation Voltage 2.8 kv dc, 1.0 minute C Impulse Voltage 5.0 kv peak, 1.2 X 50 us C Oscillatory Surge Withstand 2.5 kv, 1 MHz C Fast Transient 4.0 kv peak, 10 X100 ns C EMI Volts/Meter 35 V/m, 25 MHz -1.0 GHz C ESD Electro-static discharge Table 1-6. Metering Accuracy Quantity Average % Error Maximum % Error Voltage ( V) Current ( A) Watts (PF = 1.0) VARs (PF = 0) Watts (PF = 0.866) VARs (PF = 0.866) * The error is less than the values shown. The average error is the error averaged over a long period of time (1 minute). The maximum error is a momentary maximum as read from the metering screen. Table 1-7. Dimensions and Weight Parameter English Units Metric Units Height (3 RU) in mm Width in mm Depth in mm Weight (max / all components) lbs kg Product Overview 1-9

32 Functional Specifications Operating Units Impedance Measuring Units Refer to Settings Table for complete settings data. Three forward phase and ground zones with independent reach and timer settings for step distance protection. Additional forward and reverse phase and ground zones for pilot protection or other user function. Each zone has six impedance mho units. They are: 2 - Three phase impedance units 1 - Phase-to-phase impedance unit, and 3 - Phase-to-ground impedance units The impedance units are quadrature polarized having variable mho characteristics settable (5A) or (1A) ohms. Zone-2, Zone-3, forward pilot and reverse pilot zones have a time delayed trip setting of 0.0 to 10.0 seconds. Zone-1 has three additional ground unit with quadrilateral characteristics. Blinder Units Two sets of impedance blinders provide for out-of-step block and trip functions, and load encroachment logic. Overcurrent Units Instantaneous (Type 50) Units High set A. (5A) or A. (1A) phase unit for high-speed detection of multi-phase faults. High set A. (5A) or A. (1A) ground unit for high-speed detection of phase-to-ground faults. High set A. (5A) or A. (1A) negative sequence unit for greater sensitivity and high speed detection of phase-to-phase faults. All high set units can be set to trip with or without directional supervision. Medium set A. (5A) or A. (1A) phase unit for overcurrent detection of multi-phase faults and supervision of phase impedance units and OS functions. Medium set A. (5A) or A. (1A) forward directional ground unit for detection of phase-toground faults, SPT logic, pilot logic, and supervision of ground impedance units. Medium set A. (5A) or A. (1A) forward directional negative sequence unit for greater sensitivity and detection of phase-to-phase faults. Medium set ground units can be set to trip with a time delay (0.0 to 10.0 sec) to provide greater sensitivity to high resistance ground faults. Medium set negative sequence units can be set to trip with a time delay (0.0 to 10.0 sec) to provide greater sensitivity to phase-to-phase faults. Low set A. (5A) or A. (1A) phase unit for overcurrent detection of multi-phase faults, close-into-fault, and accelerated trip logic Product Overview

33 Low set A. (5A) or A. (1A) ground unit for detection of phase-to-ground faults, close-intofault, out-of-step-block, loss-of-potential, and pilot logic. Low set A. (5A) or A. (1A) negative sequence unit for greater sensitivity and detection of phase-to-phase faults, and out-of-step-block logic. Time Overcurrent (Type 51) Units 3 Phase, inverse time, overcurrent phase units A. (5A) or A. (1A) with directional or Zone-2 torque control. 1 Ground, inverse time, overcurrent phase units A. (5A) or A. (1A) with directional or Zone-2 torque control. 1 Negative sequence, inverse time, overcurrent units A. (5A) or A. (1A) with directional or phase, and/or ground Zone-2 torque control. Settings constants are based on the proposed IEEE Standard C37.112, and emulate any curve including CO and IEC time curve characteristics. Selectable reset time curve. Voltage Units Three independent phase undervoltage units with (the same) threshold setting (40-60 V) for low voltage alarm, loss-of potential logic and other user applications. Zero sequence voltage element (3V 0 ) with an overvoltage threshold setting (0-120 V) for loss-of potential logic and user applications. Operating Unit Accuracy Impedance Units Impedance reach accuracy is less than 3% underreach and 0% overreach. All impedance unit operating times are based on the system equivalent source (to relay setting) impedance ratio (SIR), and are determined below in Figure 1-8 for a SIR range of 1 to 20. Figure 1-8. Impedance Unit Operating Time Product Overview 1-11

34 Time in Cycles ABB REL 512 Line Protection and Breaker Control Terminal Instantaneous Overcurrent Units The operating accuracy of the overcurrent units is less than 2%, and the dropout to pickup ratio is greater than The operating time of the instantaneous overcurrent units are defined in Figure Maximum 0.5 Minimum Multiples of Overcurrent Unit Pickup Setting 20 Inverse Time Overcurrent Units Maximum operating time error for the applied current is the computed time based on settings plus 40 ms. Voltage Units Figure 1-9. Instantaneous Overcurrent Unit Operating Time The operating accuracy of the phase undervoltage units is less than 2% of the setting, and the dropout to pickup ratio is less than The operating accuracy of the ground overvoltage unit is less than 2%, and the dropout to pickup ratio is greater than The operating accuracy of the phase overvoltage units is less than 2%, and the dropout to pickup ratio is greater than Directional Unit Sensitivity Table 1-8 shows the minimum operating sensitivity measured by test for each directional unit. The sensitivity is measured in VA for voltage polarized units and IP x I for current polarized units. Also the zero and negative sequence unit VA product sensitivities are computed using 3V X 3I. Note the unit compared. Refer to Section 5 for more detailed information on directional unit sensitivity Product Overview

35 Table 1-8. Directional Unit Sensitivity Directional Unit Product Minimum Sensitivity VA or I 2 With Constant Polarizing Quantity With Constant Current = 0.25 A Three-phase V XY X I Z (V XY = 1.73) < 2.0 < 2.8 Negative Sequence Voltage (3V 2 ) Zero Sequence Voltage (3V 0 ) Zero Sequence Current (I P ) 3V 2 X 3I 2 (3V 2 = 1.0) < 1.0 < 1.0 3V 0 X 3I 0 (3V 0 = 1.0) < 1.0 < 1.0 I P X 3I 0 (I P = 0.5) <1.0 < 1.0 Time Delay Timers The time delay trip timers operate with a 1.25 cycle resolution. Considering typical measuring unit operating times of 0.75 to 1.5 cycle, output relay time of 4 to 6 ms and this resolution, total operating times are consistently 30 to 50 ms greater than setting for 60 Hz operation and 40 to 60 ms for 50 Hz operation. Operating times are never less than the setting. This allows a reduced operating time and greater accuracy. For example at 60 Hz, if the desired setting is 0.5 seconds then set the relay to Twenty Zone-2 trip operations with a 0.46 setting will statistically produce the following: Average operating time = seconds Maximum operating time = seconds Minimum operating time = seconds (0.24% error) (1.16% error) (1.7% error) NOTE: Time delay operating times include the set time delay, plus the measuring unit operating time, plus 40 ms. Testing near the boundary or threshold of an impedance measuring unit may result in longer operating times than expected. Operating time testing should always be done with faults applies under 80% of the reach setting. Product Overview 1-13

36 Protection Functions Basic Distance Functions Three zone step distance protection. Selectable Zone-1 extension logic for high speed clearing of remote end zone faults. Selectable loss of load accelerated trip for high speed clearing of remote end zone faults. One cycle operation for Zone 1, forward pilot and reverse pilot zone operations within 80% of the respective zone reach setting. Inherent immunity to CCVT and offset dc current transient prevents Zone 1 overreaching. Selectable power swing block for each tripping zone and/or out-of-step trip using double blinder logic. Load restriction logic. Overcurrent Functions Directional high set overcurrent phase and ground protection. Time delay overcurrent phase and ground protection. Zone 2 or directional torque-controlled phase, ground and negative sequence overcurrent protection. Close into fault detection and tripping. Stub bus protection. Unequal pole closing load pickup logic. Loss of current monitoring. Voltage Functions Loss of potential blocking. Single and three phase undervoltage supervision and output. Ground overvoltage supervision and output. Pilot Functions Options for blocking, unblocking, Permissive Overreaching Transfer Trip (POTT) and Permissive Underreaching Transfer Trip (PUTT) schemes. Transient block logic. Three-terminal line protection logic. Weakfeed logic. Blocking coordination timer. Pilot receive pulse stretcher. High speed carrier start for blocking system Product Overview

37 Breaker Failure Functions (Optional) Single breaker failure scheme. Breaker retrip. Short time timer for multiphase faults. Long time timer for all faults. Settings Eight relay settings groups with local or remote control of setting selections. Change settings groups with binary input, ASCII interface or network control. Automation Functions Open and close breaker. Operate I/O metering. Reclose High speed tripping recloser initiate. Time delayed tripping reclose initial. Reclose block functions. Optional 4 shot reclosing with voltage and synchronism checks. Inputs and Outputs Inputs Twelve independently programmable isolated dc voltage inputs. Outputs Twelve programmable trip rated contacts rated 30 A make and carry for 1 sec, and 6 A continuous for trip, control and alarms. Six trip rated contacts rated 30 A make and carry for 1 sec, and 6 A continuous for trip, pilot start and pilot stop. I/O Mapping and Programmable Logic Mapping logic control of output contacts using relay logic signals and binary voltage inputs. Product Overview 1-15

38 Fault Information LED s 24 LED s that include: Fault type LED s: A phase, B phase, C phase, Ground. Six trip type LED s: Zone 1, Zone 2, Zone 3, Pilot, Overcurrent, Trip and Fault Monitoring LED s: In service, Pilot Enabled, Self-Testing, LOP/LOI, 50M (current level), Breaker 1 and Breaker 2 status, and Reclosing. Fault Location Fault location accuracy is dependent on the accuracy of fault voltage measurement. Generally less than 2% error is expected for multiphase faults and phase-to-ground faults with no fault resistance. Phase-to-ground fault location accuracy with appreciable fault resistance will be affected by the remote source, load current, and fault resistance magnitude. Faulted phase selection is based on the relative fault current value in each phase after the load current is removed. 100% accuracy is expected. Digital Fault Recording 15 most recent fault records include: 2 prefault cycles 14 post fault cycles Sampling rate 20/cycle Voltage and current analog channels 165 digital channels for operating unit, DSP logic, and I/O status at ms resolution Fault Distance Trip (LED) Summary Programmable Logic Combines key relay operating unit and logic signals. AND and OR gates with negation. On and off delay timers. Flip-flop latches Product Overview

39 Catalog Information (V2.x only) Options Catalog # R512 H6B1 N4DN1 N Mounting Horizontal Vertical H V H Frequency 50 Hz 60 Hz Current Rating 1.0 A 5.0 A A B B Battery Voltage 24 V dc 48 V dc 110/125 V dc 220/250 V dc Breaker Failure Protection With BF Logic None B N N Multi-shot Reclosing Reclosing* 1 None Network Port #1 Modbus Plus* 2 DNP 3.0* 2 None M D N D Future None N N Trip Outputs Standard (4-6 ms) High-speed* 3 (< 1.0 ms) Dust Proof Cover Dust Proof Cover None D N N 1. Requires separate reclose module. 2. Requires separate network communications module 3. Requires High-speed FET output assist module. All relay contact outputs close the controlled circuit in less than 1 ms after relay assertion. Product Overview 1-17

40 Notes 1-18 Product Overview

41 Acceptance, Installation, and Maintenance Acceptance The relay should be tested in accordance with the acceptance test procedure provided in Section 6, to insure the relay is received without damage and is functioning properly. Installation Dimensions - inches (mm) Figure 2-1. Top View Acceptance, Installation, and Maintenance 2-1

42 Figure 2-2. Front View 2-2 Acceptance, Installation, and Maintenance

43 Figure 2-3. Rear View Acceptance, Installation, and Maintenance 2-3

44 External Connections AC and DC Connections Figure 2-4. Terminal Blocks TB1 and TB2 (See Figure 3 Rear View) 2-4 Acceptance, Installation, and Maintenance

45 I/O Connections Note: Refer to Section 8, for Optional Reclosing I/O Connections to TB6, TB7, and TB8. Figure 2-5. Terminal Blocks TB3, TB4 and TB5 (See Figure 3 Rear View) Acceptance, Installation, and Maintenance 2-5

46 Table 2-1. I/O Connection Table Function Terminal Block + DC - DC NO/NC Jumper Input 1 (Programmable) TB3 1 2 N/A Input 2 (Programmable) TB3 3 4 N/A Input 3 (Programmable) TB3 5 6 N/A Input 4 (Programmable) TB3 7 8 N/A Input 5 (Programmable) TB N/A Input 6 (Programmable) TB N/A Input 7 (Programmable) TB N/A Input 8 (Programmable) TB N/A Input 9 (Programmable) TB N/A Input 10 (Programmable) TB N/A Input 11 (Programmable) TB4 1 2 N/A Input 12 (Programmable) TB4 3 4 N/A Relay 1 (In Service/Alarm) TB4 5 6 JP18 Relay 2 (Programmable) TB4 7 8 JP17 Relay 3 (Programmable) TB JP16 Relay 4 (Programmable) TB JP15 Relay 5 (Programmable) TB JP14 Relay 6 (Programmable) TB JP13 Relay 7(Programmable) TB JP12 Relay 8 (Programmable) TB JP11 Relay 9 (Programmable) TB5 1 2 JP10 Relay 10 (Breaker Failure Initiate or Trip Seal A) TB5 3 4 JP9 Relay 11(Time Delay Reclose Initiate or Trip Seal B) TB5 5 6 JP8 Relay 12 (High Speed Reclose Initiate or Trip Seal C) TB5 7 8 JP7 Relay 13 (Fault Inception) TB JP6 Relay 14 (Pilot Channel Stop) TB JP5 Relay 15 (Pilot Channel Start) TB JP4 Relay 16 (3P Trip Seal or SPT Trip Seal A) TB JP3 Relay 17 (3P Trip Seal or SPT Trip Seal B) TB JP2 Relay 18 (3P Trip Seal or SPT Trip Seal C) TB JP1 NOTES: 1. DC polarity must be followed to insure correct operation and prevent damage to relay. 2. Relay 1, 2,..., 18, as identified above, are labeled in reverse order on the main printed circuit board. That is Relay 1 is labeled K18 and Relay 18 is labeled K1, etc. 3. Relay configuration, Normally Open (NO) or Normally Closed (NC), is accomplished by placing the associated jumper (shown above) in the desired position. 4. Relays 10, 11 and 12 are used for single pole trip output #2 which are enabled by the setting SPT BKR2 OUT. These can also be used for additional three pole tripping if additional trip outputs are required. 2-6 Acceptance, Installation, and Maintenance

47 Figure 2-6. Typical REL 512 DCB Pilot Scheme Connection to TC-10B, Part 1 Acceptance, Installation, and Maintenance 2-7

48 Figure 2-7. Typical REL 512 DCB Pilot Scheme Connection to TC-10B, Part Acceptance, Installation, and Maintenance

49 Communication Connectors Serial Port 1 (Front View, Figure 2-2): DB9, (female) DCE, RS232 for direct cable connection to PC serial port. Serial Port 2 (Rear View, Figure 2-3): DB9, (male) DTE, RS232 or RS485 for direct cable connection to Modem or RS232 switch serial port. A null-modem cable or adapter is required for a PC serial port connection. Network Port 1 (Rear View, Figure 2-3): DB9 (female) connector for Network 1 protocol. IRIG-B Connections (Rear View, Figure 2-3) Screw terminals for connection to demodulated IRIG-B signal source. Standard chassis BNC connector for connection to modulated IRIG-B signal source. Caution: Connecting the incorrect serial cable from you computer or modem for ASCII communications to the network port may result in damage to the network card. Internal Connections I/O Jumpers All binary voltage inputs and contact outputs have associated jumpers to allow application flexibility, but require correct positioning to assure desired operation. The following sections discuss the correct application of jumpers. Binary Input Jumpers Version 1.x relays do not have jumper selectable binary voltage input ratings. They are fixed and have the same rating as the relay s input power supply. Output Relay Contact Jumpers Each output relay contact has a jumper to set its normal position (relay de-energized) as normally closed (N/C) or normally open (N/O). There are three jumper pinholes per output relay contact. The common pinhole (used for both connections) is labeled JP##, the normally open pinhole is labeled N/O and the normally closed pinhole is labeled N/C. A jumper connection is made between the common pinhole and either N/O or N/C. The position for Relay 1 as identified in Table 2-1 is set by jumper JP18. The factory setting for JP18 is N/C. The remaining relay contacts are all set to N/O. Relay output contact numbers (Relay #) and the corresponding jumper numbers (JP #) are shown on Table 2-1. Acceptance, Installation, and Maintenance 2-9

50 Maintenance The protection terminal is self-supervised. No special maintenance tests are required other than the RAM battery repacement. The battery is Panasonic 3V number BR2030 and has a shelf (relay deenergized) life of 5 to 7 years. There is no drain on the battery while the relay is inservice, thereforebattery life of more than 20 years is expected. Also, company directives for maintenance of the power system should be followed and in this respect, the REL512 can be regarded as a standard relay device in your system. Notes 2-10 Acceptance, Installation, and Maintenance

51 Operation Communicating With the Relay There are several ways to communicate and exchange information with the relay. These include the front panel mounted UI for a manual interface, LED s for a quick visual status of the relay and operation information, IRIG-B for updating the relay s time, and front and rear communication ports for remote computer access. Front Panel User Interface The front panel UI is a 4 line X 16 character/line Liquid Crystal Display (LCD) with 4 directional scrolling keys and 2 push-buttons. In addition there are 24 LED s and a push-button reset. All active group settings, 15 most recent sets of targets and metering display quantities, can be viewed or edited from the front panel UI. Caution: The UI cannot be disconnectedwhile the relay is in-service The UI provides a metering and target display, and allows a user to view or edit the active group settings. The view mode is suitable to access relay information for review such as settings, product information and metering, and target information. The editing mode is more appropriate for changing relay settings. Below is a brief description explaining how to use the UI for viewing, or editing relay settings. View Mode After powering up the relay, the UI will be in metering mode. To view or edit settings, press any of the 4 directional scrolling keys or either of the 2 push-button keys. After a brief delay, there will be a menu to select view or edit settings, or to view product information. The user may traverse through the settings menus in view mode at will. The menus are set up in a hierarchical fashion. The E key pushes into the next menu level. The C key pops to the previous menu level. Arrow keys in the left column of the display show the present level menu items and indicate how to scroll through them. If the user selects edit mode, they will be required to enter a password to continue. The default factory password is ABB. When leaving the menus in the edit mode, the user will be warned that the unit must reset to allow their changes to take effect. Editing Mode Figure 3-1. Front LCD User Inferface While editing settings, the setting being changed is located on line 3 of the LCD display. The cursor and auto-repeat are both active when editing settings. The right and left arrow keys are used to parse back and forth between digits or characters. If the setting is a selection, the left arrow scrolls through the different selection items. When editing digits or characters, the up and down arrows are used to increment or decrement the digit or character above the cursor. When editing digits, all leading and trailing zeros are erased during parsing. If the user parses to the right of the least significant digit, a Operation 3-1

52 zero will be added to the right side of the value. This new digit may then be edited. If the user parses to the left of the most significant digit, a zero will be added to the left side of the value. This new digit may now be edited. The leading digit may be any digit or a + or -. All other digits may only be digits. If a value has a decimal point, the decimal point may not be removed. There will always be a leading zero for decimal values. Once a value has been edited, pressing E saves it. Pressing C may terminate the edit session. Digital values may be set to any value that will fit on one line of the display. When a value is entered, it is checked against an upper and lower limit. If the new value is outside these limits, it will be set to the appropriate upper or lower limit. If a value is modified, the change does not take effect until exiting the UI menus and selecting reset when prompted resets the unit. LED s The following table shows the relay logic signals that operate the LED s. Table 3-1. LED Functions LED PROTECTION IN SERVICE PILOT ZONE-1 ZONE-2 ZONE-3 A PHASE B PHASE C PHASE G/Q Function (LOGIC SIGNALS which activate LED) Relay energized and funcitoning properly. Shows the operation of the direct tripping of the Forward or Reverse pilot zones if tripping is enabled. Shows Pilot Tripping if PILOT SYSTEM is enabled. FWP PILOT TRIP, RVP PILOT TRIP, PILOT TRIP COMBINED, PILOT WEAKFEED TRIP. Zone-1 tripped. ZONE 1 TRIP, LLT Zone-2 tripped. ZONE 2 TRIP Zone-3 tripped. ZONE 3 TRIP Fault involves A phase (Phase selector) Fault involves B phase (Phase selector) Fault involves C phase (Phase selector) Fault involves Ground (Phase selector) or was a zero or negative sequence overcurrent trip. MEDIUMSET GROUND TRIP, MEDIUMSET NEGATIVE SEQUENCE TRIP, HS N TRIP, HS Q TRIP, 51N BACKUP TRIP, 51Q BACKUP TRIP 50/51 An instantaneous or inverse time overcurrent unit operated, or a close into fault trip. HS TRIP, MEDIUMSET GROUND TRIP, MEDIUMSET NEGATIVE SEQUENCE TRIP, 51P BACKUP TRIP, 51N BACKUP TRIP, 51Q BACKUP TRIP, CLOSE INTO FAULT TRIP FAULT TRIP PILOT IN SERVICE LOP/LOI RECLOSE IN SERVICE* LOCKOUT* SYNC-CHECK* HBDL* HLDB* A fault has occurred and a digital fault record was saved. A trip has occurred and a digital fault record was saved. TRIP SEAL, DSP TRIP SEAL, PILOT WEAKFEED TRIP The relay is set for pilot operation and the pilot enable switch (85CO) is programmed, properly wired and closed. PILOT ENABLE A loss of potential or loss of current. UNDERVOLTAGE OR LOSS OR CURRENT ALARM if BREAKER OPEN is FALSE Reclosing module is present and reclosing is in service. Reclosing logic is in the lockout state as the result of a reclosing failure or driving to lockout via external input. The power system voltages on each side of the breaker are within set limits that define synchronism. Indicates hot bus and dead line. Indicated hot line and dead bus. TRIP CIRCUIT 1 There is a problem with the trip circuit on Breaker #1 or a breaker failure trip occurred. TCM/52 ALARM 1, BREAKER FAILURE TRIP 52B-1 Breaker #1 is open when 52B-1 is programmed, properly wired and closed, or 52A-1 is programmed, properly wired and opened. 52B-2 Breaker #2 is open when 52B-2 is programmed, properly wired and closed, or 52A-2 is programmed, properly wired and opened. TRIP CIRCUIT 2 There is a problem with the trip circuit on Breaker #2. TCM/52 ALARM 2 SELF TEST The relay is self-testing. a flashing LED indicates normal relay operation. *Reclosing functions - only operational if reclosing option installed. 3-2 Operation

53 Reset Button The reset button clears the LED s. It can also be used to reset default settings. Press the reset button while energizing the relay. The left column of LES s will illuminate simultaneously. Releasethe pushbutton and the left LED s will go out. After about 5 seconds the right column will illuminate. Press and release the reset button again. The relay will boot with the default settings. Computer Communication Interfaces RS232 Ports There is one front accessible RS232 optically isolated, buffered port for local access from a portable computer for relay data interrogation, settings editing, operating and testing. The front port is a DB9/ DCE connector (female) for direct computer connection. There is one rear accessible RS232 optically isolated, buffered port for local or remote access from a PC or modem for relay data interrogation, settings editing, operating and testing. The rear port is a DB9/DTE connector (male) for direct modem or smart switch connection. Simultaneous communications through both RS232 ports is not possible. In the unattended or default mode communications is done through the rear port. If local access is desired using the front port, then communications is transferred to the front port with the correct cable interface and keystroke. Communications is switched back to the rear port 15 minutes after the last keystroke. RS232 communication can run simultaneously with network communications, DNP 3.0 or Modbus Plus. Cable Connections A standard 9 pin DTE to DCE RS232 (PC to modem) cable is required for the interface between a computer and the front port, and a modem and the rear port. To interface a computer with the rear port a null modem adapter (or separate null modem cable) is required. NOTE: Connecting the incorrect serial cable from you computer or modem for ASCII communications to the network port may result in damage to the network card. ASCII/English Protocol Off-the-shelf industry accepted communication programs such as Cross TalkÔ or PROCOMM PLUSÔ might be used to communicate with the relay in a (dumb) terminal emulation mode via either port. Also, up or down loading of settings and fault records is done using the program s Xmodem (Checksum or CRC) binary file transfer protocol. The relay is delivered with the following communication settings for both the front and rear interfaces: Bit rate change to if supported by your computer s software, serial port or modem. Word Length 8 Parity None Stop Bits 2 Optional network interfaces in addition to above may be provided depending on the substation network requirements. Operation 3-3

54 Typical Communication Program Settings The following settings are typical for communication programs. They may vary depending on your communications program and computer. Terminal Emulation DEC VT-100 or VT-102 (ANSI) Binary Transfers Xmodem (Checksum or CRC) Terminal Preferences Function, Arrow, and Ctrl Keys should be set to OFF Baud Rate (based on modem and relay setting) Data Bits 8 (relay setting) Stop Bits 2 (relay setting) Parity None (relay setting) Flow Control None Comm Port Computer s communication port Interfacing with the Relay Power up the relay and start your communications program. Open the REL 512 communications file or make the appropriate communications program settings. When the communication settings are correct, the relay will display Root Menu. If operating a Windows based program maximize your window for better overview. You advance through the menu by pressing the selected number or letter key. You backup to the previous ment by pressing < / >. Save your communication program settings for REL 512 communications. NOTE: If communication can not be established, please check the communication port settings by using the front UI. Also, remember that if you change the port settings for the active port when you are communicating with the relay, communications may be stopped. You will then need to change the settings of the communications program accordingly to reestablish communications. The REL 512 Interface Menu NOTE: The < / > key is used to return to the previous menu level. This is done to avoid conflicts with communication prograns that use the < Esc > or arrow keys. The REL 512 has been designed with a menu system that allows viewing the state of selected logic elements, as well as changing relay settings and system parameters. The menus are self explanatory. A lower level menu or function is accessed by pressing the appropriate selection key number or letter. To return to an upper level, press < / >. On the lower part of the screen, a status message showing the Active Group is continuously shown. Root Menu The Root Menu is the first menu seen upon establishing correct communications. The following Root Menu items are available: [1] View Product Information Relay product ID, serial #, software version(s), hardware status, etc. 3-4 Operation

55 [2] View Configuration Settings View only of relay configuration settings. The following functions are available with this selection: [1] Station ID [2] System Parameters [3] Comm Ports [4] Data Display & Recording [5] Set Date & Time [3] View Protection Settings View only any of 8 groups of relay protection settings. The following functions are available with this selection: [1] Distance [2] Out of Step [3] Overcurrent [4] Voltage O/U [5] System Type [6] Trip Type [7] Breaker Failure [8] Breaker Reclosing [4] View I/O Mapping View only the programmed I/O maps. The following functions are available with this selection: [1] View DSP Relay Output Map [2] View CPU Relay Output Map [3] View Binary Input Map [4] View PLC Output Map [5] Monitoring Functions Enables you to view the metering of line quantities, status of I/O, and status of operating elements and key logic signals. The following functions are available with this selection: [1] Metering [2] Binary Input Status [3] Relay Output Status [4] DSP Elements and Logic [5] CPU Logic Scope A [6] CPU Ligic Scope B Operation 3-5

56 [6] Password Functions The relay is shipped with ABB as a factory password setting. Changes can be made using this menu choice. The following functions are available with this selection: [1] Edit Configuration Settings [2] Edit Protection & I/O Map Group Settings [3] Copy Protection & I/O Map Group Settings [4] Set Active Group [5] Send Settings to Relay [6] Send Programmable Logic to Relay [7] Reset LED Panel [8] I/O Diagnostics [9] Change Password [A] Breaker Control [7] Retrieve Data The following functions are available with this selection: [1] Receive Fault Records from Relay [2] Receive Settings from Relay The above selections are self explanatory and relatively easy to follow. Root Menu items [5] Monitoring Functions, [6] Password Functions and [7] Retrieve Data, however, will be discussed in more detail. Monitoring Functions [1] Metering View the metered line quantities including phase, positive sequence, negative sequence, and zero sequence voltages and currents. Power flow quantities are also displayed. [2] Binary Input Status View the status (ON/off) of the binary inputs. ON means a voltage is applied. [3] Relay Output Status View the status (ON/off) of the contact outputs. ON means they are reverse of their normal open or closed state as set by the internal jumpers. Contacts 1 to 4 are normally set closed. Contacts 5 to 18 are normally set open. [4] DSP Elements and Logic View the operational status (Logical 1 or 0) of all the operating elements and key DSP logic signals. [5] & [6] CPU Logic Scope A & B Allows for monitoring of the logic state of selected CPU logic signals. 3-6 Operation

57 Password Functions [1] Edit Configuration Settings Refer to the Settings Tables for more information. [1] Station ID [2] System Parameters [3] Comm Ports [4] Data Display & Recording [5] Set Date & Time [2] Edit Protection & I/O Map Settings A unique feature of the relay is that it maintains one active (operational) group of settings and parameters. In order to maintain operating security from undesired tripping the active group settings cannot be edited. To edit the active group, the active group values must first be copied to another group, 8 for example, edited and then be copied back to the active group. The settings copied to the active group become the new active group settings. An alternate method is to edit the settings of a nonactive group and then make the edited group the active group. Following either process the relay will reset momentarily going out of service load the new active settings. Settings and parameters are changed by toggling the space bar to toggle between choices or entering numerical values and pressing the enter key. [1] Distance [2] Out of Step [3] Overcurrent [4] Voltage O/U [5] System Type [6] Trip Type [7] Breaker Failure [8] Configure Output Maps Selected operating units and logic signals can be mapped to operate any of 8 programmable output contacts. See I/O Mapping. [9] Configure Input Maps Any of 12 relay binary (voltage) inputs can be mapped to any of a number of selected logic signals,... Channel Receive #1, Channel Block #1, Open Breaker 52b, etc. See I/O Mapping. [A] Breaker Reclosing Single breaker reclosing logic settings. Requires reclosing option module to be present. [3] Copy Protection & I/O Map Settings Copy the complete protection and I/O map group settings from one group to another. If the destination group is the active group, the relay will reset momentarily going out of service while loading new settings. [4] Set Active Group The active group is the group of settings that the relay is using for processing. This function allows setting another group to be active. The relay will reset when setting a new group to be the active group. Operation 3-7

58 [5] Send Settings to Relay Sends an off-line edited binary settings file to the relay via a communications program using Xmodem binary file transfer protocol. NOTE: Be sure to select the correct menu item numbers [5] or [6] when sending settings or programmable logic is the relay. For example, if sending a programmable logic file (*.pl) and you incorrectly select menu item [5] the transfer is attempted but the file is not accepted. A note indicating failure is displayed. [6] Send Programmable Logic to Relay Sends an off-line developed binary programmable logic file to the relay via the communications program using Xmodem binary file transfer protocol. NOTE: The prgroammable logic file (*.pl) used, must be sent (or resent) to the realy after the settings file (*.bin) has been sent tot he relay to assure proper implementation of the programmable logic. [7] Reset LED Panel Clears the front panel LEDs. [8] I/O Diagnostics This function tests the operation of the LEDs and relay outputs [1] Cycle LEDs. [2] Cycle Relay Outputs [3] Single Relay Output [9] Edit Relay Password This allows editing of the relay password. You must know the existing password to change it. The default password is ABB or abb you have 15 minutes after energizing the relay to use this password to change to a new one. [A] Breaker Control This function allows the operation of the Trip contacts and a programmable output contact, Close, for operation of the connected power circuit breaker. [1] Open Breaker [2] Close Breaker [3] Close Breaker with Supervision Both Open Breaker and Close Breaker are unsupervised operations, which cause operation of the output contacts regardless of system conditions. Close Breaker with Supervision requires the optional reclosing module and operated through the Manual Close supervision functions. Retrieve Data [1] Fault Record View the fault data summary currently stored in the relay and download a selected fault record. Select from a list of the latest 16 available records. The REL 512 is set to download using XModem protocol. Follow the instructions of your communication program for downloading files. Refer to AN-54L-00 in Section 10 for specific instructions using Windowsä Hyperterminal. [2] Settings Download the relay settings. 3-8 Operation

59 I/O Mapping The Logic State of operating units or selected logic signals can be configured (mapped) to operate any of 8 programmable relay outputs. There are also 12 binary inputs that can be mapped to selected input signals for logic which requires external (to the relay) status information...52b, 85CO, etc. Mapping an operating element or logic signal with a binary input or contact output is done by placing an X at the corresponding intersection in the appropriate mapping matrix. This is done by moving the cursor to the desired intersection and toggling the space bar. The mapped signal can be removed by locating the cursor under the X and toggling the space bar. When multiple signals are mapped to one output then the output responds as an OR gate to the mapped signals. When multiple inputs are mapped to one signal then the signal responds as an OR gate to the mapped inputs. It is also recommended to Clear All Maps before beginning map editing. DSP Signals Relay Output PRT:... X... PFT: DSP Trip:.... X.. Z1 Trip: HS Trip: N Overvoltage: Reverse 3PH: Forward 3PH: X Reverse GF: Forward GF: OSB: PH Undervoltage: Undervoltage: M Supv 3PH:. X M Supv PHASE: Operation 3-9

60 Relay Inputs and Outputs Output Contacts Fixed (Non-Programmable) Outputs The following logic signals are permanently mapped to the indicated contacts. Table 3-2. Fixed Outputs Signal or Function Three Pole Trip In Service Failure Breaker Failure Initiate Time Delay Reclose Initiate High Speed Reclose Initiate Fault Inception Pilot Channel Stop Pilot Channel Start Trip Trip Trip Single Pole Trip In Service Failure Breaker Failure Initiate Time Delay Reclose Initiate High Speed Reclose Initiate Fault Inception Pilot Channel Stop Pilot Channel Start Trip Phase A-1 Trip Phase B-1 Trip Phase C-1 Relay Output Operation

61 Programmable Outputs There are two methods of programming outputs 2 through 9. One method is to use the off-line programmable logic editor, RELLOGIC, and program the outputs using a AND and OR gates, inverters, on and off-delay timers and latches. Information and available logic signals for programming with RELLOGIC is found in Section 7. A second method of programming the outputs is to use the direct mapping function that ties a relay logic signal to an output contact. There are no associated logic gates, timers and etc. This mapping can be done as described in the previous discussion of I/O Mapping. This method is referred to as mapping. The following DSP and CPU measuring unit and logic signals are mappable to contacts 2 through 9. DSP Signals HS TRIP DSP TRIP PRT 50M SUPV 3PH 3PH UNDERVOLTAGE REVERSE GF REVERSE 3PH OSB Z1 TRIP PFT 50M SUPV PHASE UNDERVOLTAGE FORWARD GF FORWARD 3PH 59N OVERVOLTAGE Programmable CPU Logic Signals BREAKER FAILURE TRIP BREAKER FAILURE RETRIP INNER BLINDER OUTER BLINDER LOSS OF CURRENT ALARM HS LOP BLOCK SET PILOT CHANNEL START PILOT CHANNEL STOP ZONE 2 TRIP ZONE 3 TRIP RECLOSE BLOCK BKR FAIL RB HSRI TDRI BREAKER FAILURE INITIATE* TCM/52 ALARM 1 TRIP COIL 1 MONITOR TCM/52 ALARM 2 TRIP COIL 2 MONITOR NETWORK 52 CLOSE *BREAKER FAILURE INITATE may be used to program additional three-pole trip outputs (TRIP SEAL). The I/O logic signal functions are defined in Section 4. Operation 3-11

62 Programmable Binary Inputs The following inputs are programmable to the indicated logic signal. 85CO 1 CHANNEL BLOCK 1 2 CHANNEL BLOCK 2 CHANNEL RECEIVE 1 2 CHANNEL RECEIVE 2 89B CLOSED BREAKER 1 CLOSED 52A 4 BREAKER 1 OPEN 52B 3 TRIP COIL 1 MONITOR BREAKER 2 CLOSED 52A 4 BREAKER 2 OPEN 52B 3 TRIP CIOIL 2 MONITOR XBFI 86T XLED RESET XDFR TRIP BLOCK 1 85CO Pilot carrier on/off (or cutout) is a required input for pilot logic operation. 2 CHANNEL RECEIVE 1 and CHANNEL BLOCK 1 (Channel Block required for Directional Comparison Unblocking logic) must be programmed for use in two terminal applications. That is, inputs labeled Channel Block 1 and Channel Receive 1 are required for both two and three terminal applications. Inputs labeled Channel Block 2 and Channel Receive 2 are also required for three terminal applications. 3 If used, BREAKER 1 OPEN 52B and BREAKER 2 OPEN 52B must be mapped to the same input for single breaker applications. Separate inputs are required for two breaker applications... ring and 1-1/2 breaker. 4 If used, BREAKER 1 CLOSED 52A and BREAKER 2 CLOSED 52A must be mapped to the same input for single breaker applications. Separate inputs are required for two breaker applications... ring and 1-1/2 breaker. Miscellaneous Functions Trip Coil Monitoring Trip coil monitoring looks for no voltage across the open trip contacts while the breaker is closed (52a closed) or a voltage when the breaker is open (52a open) to indicate a trip coil or circuit problem. To implement trip coil monitoring an external jumper needs to be made from the monitored trip output contact terminals to the binary input terminals that have been programmed for trip coil monitoring. For example, breakers #1 is to be tripped by relay 16 and monitored by input 5, and breakers #2 is to be tripped by relay 17 and monitored by input 6, the following connection chart would apply. The logic signals TRIP COIL 1 MONITOR and TRIP COIL 2 MONITOR must be mapped to input 5 and 6, respectively, for this example. Table 3-3. Trip Coil Monitoring Connections Breaker From Trip Relay Terminals To Binary Input Terminals TB5-15 (+) TB3-9 (+) 5 TB5-16 (-) TB3-10 (-) TB5-17 (+) TB3-11 (+) 6 TB5-18 (-) TB3-12 (-) 3-12 Operation

63 Table 3-4. External Switch Operation Figure 3-2. Trip Coil Monitoring Scheme Changing the Settings from an External Switch A binary switch can be used to change relay settings to any of setting groups 1-7. Three binary inputs are required, 10, 11 and 12. The inputs are combined in the relay to determine the correct group. To implement this operation the External Settings Change setting must be set to ENABLE. If enabled, the programmable inputs are used for this function. If disabled, the programmable inputs are available for other functions. This setting is found in the System Configuration Settings/System Parameters. A binary switch is used to apply dc voltage at the desired input terminals for at least 10 seconds. After 10 seconds the relay will reboot. Upon initializing the binary inputs will be read and the appropriate settings loaded. The new active group can be confirmed by viewing the UI display during the initializing process. Binary Input Terminal TB3-19 TB3-20 TB4-1 TB4-2 TB4-3 TB4-4 dc Voltage Polarity To Set Group: No Change Programmable Logic 1 Indicates an applied dc voltabe for more than 10 seconds. Programmable logic can be used to provide auxiliary protection, control and testing functions unique to the application. The programmable logic files are created off line using RELLOGIC software (discussed in Section 7) and uploaded to the relay via your communications program. Viewing the PLC Mapping from the relay s View I/O Mapping in the main menu will allow you to see which contacts are being controlled by the programmable logic. There should be no mapped contacts on a new unit. If up loading new logic, a test procedure defined by the person /department responsible for developing the logic should be followed. Operation 3-13

64 Notes 3-14 Operation

65 Settings and Application This section provides detailed application and product setting information for engineers evaluating the suitability or characteristics of the relay; or by those who are determining the settings for applications, or providing instructions or documentation for use within their organizations. The application of each setting and all I/O logic signals are discussed. Settings Notation There are three basic types of settings. The first defining the relay setup parameters, the second defining the threshold operating value of the relay measuring elements (units), and the third defining logic operations. The following nomenclature defines the relationship between the settings and their application. Relay Configuration Parameter Settings SETTING (Configuration Parameter) The setting is the value (or choice) of the relay configuration parameter... CT ratio, communication bit rate, substation name, etc. The setting is shown in bold capital letters. The configuration parameter is shown in bold type and within parenthesis. Operating Element Settings SETTING (Operating Element Name) Logic Variable Name The setting is the threshold value for which the relay operating element s output, the logic variable, changes state from logical 0 (False or not-operated) to logical 1 (True or operated). The setting is shown in bold capital letters. The operating element name which the setting controls is shown in bold type and within parenthesis. The logic variable name, which is the output of the relay operating element and used with the relay logic is shown in normal italics. The logic variable name is also used as the reference name for the operating element parameter...current, voltage, ohms, etc. For example: for blocking pilot applications, the low set ground current, 50NL, must be coordinated with the remote terminal s medium set ground current, 50NM. Logic Operation Settings SETTING (Logic Operation) The setting is used to enable or control relay logic operations...close into fault, out of step, loss of potential, etc. The setting is shown in bold capital letters. The relay logic operation is shown in bold type and within parenthesis. Protection I/O Mapping LOGIC SIGNAL NAME Also included in this manual are the definitions of logic signals that can be mapped (programmed) to either binary voltage inputs or a binary contact outputs. Settings and Application 4-1

66 Relay Configuration Settings that pertain to the relay s location and general application are reviewed here. Relay Location and Identification STATION NAME (Substation Identification Name) The name of the substation where the relay is applied. This insures a positive identification of the relay on disturbance records or when accessing the relay through remote communications. BAY NAME (Bay Identification Name) The identification of the breaker bay (or breaker number) in the substation where the relay is applied. This insures a positive identification of the relay on disturbance records or when accessing the relay through remote communications. LINE NAME (Line Identification Name) The name of the protected line (or remote terminal/substation name) where the relay is applied. This insures a positive identification of the relay on disturbance records or when accessing the relay through remote communications. NOTE: Disturbance records are the digital fault records of system disturbances recorded and saved by the relay. Instrument Transformer Connections VT RATIO (Voltage Transformer Ratio) The turns ratio of the device that reduces system voltage to the appropriate level for the relay, for example 69000:69 volts for use on a volt system, to give a ratio of 1000:1. In this example the setting would be CT RATIO (Current Transformer Turns Ratio) The turns ratio of the device that reduces primary circuit current to the appropriate level for the relay, for example 1200:5 multi-ratio used on the 400:5 tap corresponds to an 80:1 ratio. The setting would be 80. Power System Parameters GND DIR POL (Ground Directional Polarization) Several choices exist for polarizing of the ground directional units. Zero sequence voltage polarizing (3V 0 ) negative sequence voltage polarizing (3V 2 ) or dual polarizing 3V 0 / I P may be selected. The zero sequence voltage polarizing is developed internally using the phase-to-ground voltages supplied to the relay. No external wye-ground-broken-delta auxiliary transformer is required. Negative sequence voltage polarizing is generated internally by the directional algorithm and is compared to the negative sequence current to establish the direction to a fault. Dual polarizing utilizes two directional measurements, one using zero sequence voltage polarizing (3V 0 ) and the other using zero sequence current polarizing( I P ), each then being compared with zero 4-2 Settings and Application

67 sequence current (3I 0 ) to establish the direction to a fault. The two measurements function in an OR mode. Either measurement may provide a common output to supervise other relaying elements. Zero sequence current polarizing ( I P ) requires the availability of a separate current input from a power transformer neutral or delta winding. For short line applications in which no zero sequence mutual problems exist, zero sequence voltage supervision is preferred. For long line applications in which no zero sequence mutual problems exist, dual polarizing is useful. The level of the two polarizing quantities are complementary for variations in source impedance and ground fault location, and also no detrimental effects occur when the polarizing current is not available. Negative sequence voltage polarizing is most useful in long line applications where zero sequence mutual problems exist. Negative sequence mutual is insignificant and zero sequence mutual does not influence a negative sequence directional measurement. In general, zero sequence voltage is higher than negative sequence voltage at the fault, but decreases more rapidly the farther away from the fault it is measured. This makes the use of zero sequence voltage polarizing preferable in short line applications where no mutual problems exist. EXT SET SELECT (External Settings Selector) If this setting is set to ENABLE then three binary inputs, 10, 11, 12 are used to change the active settings group. The binary combination of the three bits define the new group. The combinations for inputs 10, 11,12 are: Reset and no action Set group #1 active Set group #2 active Set group #3 active Set group #4 active Set group #5 active Set group #6 active Set group #7 active Data Display and Fault Recording DATA CAPTURE (Data Capture Recording) A fault record is recorded with every fault inception and trip the relay sees. The selected setting, however, determines if the fault record is to be saved. There are three settings, DVDI, PILOT and TRIP. NOTE: When bench testing both the voltage and current must change to operate the Fault Inception mechanism for any records to be captured. (Voltage change at least 7 volts and current change at least 0.5 amperes.) DVDI is the fault inception and will save any record collected. This will include very remote faults as well. This could result in the saving of a large number of undesired records depending on the number of system disturbances. DVDI setting is recommended only when troubleshooting. PILOT requires that the forward or reverse pilot impedance units operate to record a fault record. The coverage is determined by the forward and reverse pilot unit reach settings. If a pilot unit operation occurs within 14 cycles of the fault inception one record is saved. If a trip occurs more than 14 cycles after fault inception, which is the result of a fault within the pilot zones, a second record will be saved. PILOT is the default setting. The Fault and the respective faulted phase (A, B, C, G/Q) LEDs will illuminate and the LCD will display the fault location with the recording of a fault record. A trip does not have to occur. Settings and Application 4-3

68 TRIP records the same as the PILOT setting except illumination of the LEDs will occur only when the relay trips. The LCD will still display fault information for non-trips where a record is saved. UNITS PRI/SEC (Analog Data Display in Primary or Secondary Units) This choice allows voltage and current values, displayed on the metering screen and UI or recorded to be expressed in secondary terms or in primary terms. The secondary values are those actually applied to the relay while the primary values would be secondary values multiplied by the CT or VT ratio to give the actual power system values. This is a matter of personal choice. Communication There are three communication ports used for the customer to edit settings and access data generated or recorded by the relay. An RS232 (DB-9, female) serial interface is provided on the front of the relay to provide convenient local access to the relay with a portable PC computer. A second RS232 (DB-9, male) serial interface is provided on the rear and is intended for remote communication access through a modem. A third port is available for interfacing the relay to a substation automation system or SCADA. The physical connection will vary with the communication protocol requirements. The following defines the setting requirements for communications through these ports. NOTE: Protocol is a structured communication language and physical media that permit communications between terminal applications. Front RS232 Communication Port Settings The following settings define the data format and protocol for communicating through the front and rear RS232 ports. The settings for each port are independent and may be set differently because of different interface requirements. FRNT BIT RATE (Front Port Bit Rate) This is communication speed which the relay and the computer exchange data. It is often referred to as baud. The bit rate is limited by the terminal computer s modem and communication software. The relay allows communications at a bit rate between 2400 and 115,200 bps. FRNT DATA LGTH (Front Port Data Word Length) Word length is the number of bits used in a word. The word length or number of data bits for most modems and communications software is 7 or 8 bits. These are the choices provided by the relay. Refer to your modem and/or communications software for the appropriate word length setting. FRNT PARITY (Front Port Parity) Parity is a binary check value used in serial communications data formats to perform basic data communications error checks. The parity settings available with basic serial communications are no parity, odd parity or even parity. These are the choices provided by the relay. Refer to your modem and/or communications software for the appropriate parity setting. FRNT STOP BITS (Front Port Stop Bits) Stop bits are used to define the end of a word. The number of stop bits for most modems and communications software is 1 or 2 bits. These are the choices provided by the relay. Refer to your modem and/or communications software for the appropriate parity setting. 4-4 Settings and Application

69 Rear RS232 Communication Port Settings REAR BIT RATE (Rear Port Bit Rate) This is communication speed which the relay and the computer exchange data. It is often referred to as baud. The bit rate is limited by the terminal computer s modem and communication software. The relay allows communications at a bit rate between 2400 and 115,200 bps. REAR DATA LGTH (Rear Port Data Word Length) Word length is the number of bits used in a word. The word length or number of data bits for most modems and communications software is 7 or 8 bits. These are the choices provided by the relay. Refer to your modem and/or communications software for the appropriate word length setting. REAR PARITY (Rear Port Parity) Parity is a binary check value used in serial communications data formats to perform basic data communications error checks. The parity settings available with basic serial communications are no parity, odd parity or even parity. These are the choices provided by the relay. Refer to your modem and/or communications software for the appropriate parity setting. REAR STOP BITS (Rear Port Stop Bits) Stop bits are used to define the end of a word. The number of stop bits for most modems and communications software is 1 or 2 bits. These are the choices provided by the relay. Refer to your modem and/or communications software for the appropriate parity setting. Networks/SCADA Protocols MODBUS + This protocol is selected for network applications requiring the Modbus+ protocol. See the Modbus+ documentation for additional settings information. DNP This protocol is selected for network applications requiring the DNP 3.0 protocol. See the DNP documentation for additional settings information. Settings and Application 4-5

70 Impedance Elements The REL 512 relay has 5 zones of phase and ground protection. Zones 1, 2, and 3 are for non-pilot step distance applications. The fourth and fifth zones, called Pilot Forward (Zpf) and Pilot Reverse (Zpr), are available for pilot protection or other user programmable function. Each zone has six impedance mho units and three quadrilateral units. They are: 3 phase and phase-to-phase protection: 2 - Three phase impedance units 1 - Phase-to-phase impedance unit Phase-to-ground protection: 3 - Phase-to-ground impedance units Zone-1 has an additional set of ground quadrilateral units. Zone-1 Figure 4-1. Impedance Measuring Units Careful consideration should be given to using (or depending on) short line applications where Zone-1 for SIR is greater that 20. For these applications the operating times may be excessive for faults beyond 40% to 50% of the line. Zone-1 represents a portion of the protected transmission line near the relaying terminal. Faults in this region may be identified easily without requiring any information over a communications channel from the far terminal. This is a direct tripping function. Z1 K0 MAG (Zone-1 Zero Sequence Compensation Magnitude) The voltage appearing at the relay location for a ground fault on the protected line is influenced by the zero sequence current flowing to the fault. This influence is weighted by a factor K0 which contains both magnitude and angle. K0 is (Z0L-Z1L)/Z1L, where Z1L is positive sequence zone impedance and Z0L is zero sequence zone impedance. These are phasor values, and the total angle must be pre- 4-6 Settings and Application

71 served for use as a setting. REL 512 allows an independent choice to be made of this factor for each of the zone settings. For the Zone 1 K0, the line impedance are used. The magnitude of the total quantity (Z0L-Z1L)/Z1L is K0 magnitude and may be entered into the relay. The range of settings available is 0 to 10 in increments of Z1 K0 ANG (Zone-1 Zero Sequence Compensation Angle) The angle of (Z0L -Z1L)/Z1L is entered. The range of settings is -120 to +40 degrees in 1 degree increments. Z1 LINE ANG (Zone-1 Line Angle) This is the angle of the positive sequence impedance of the protected circuit. The range of settings is 10 to 90 degrees in 1 degree increments. Z1 PH TRIP (Zone-1 Phase Trip) The phase distance measuring units operate and execute appropriate protection or programmable logic, however, tripping can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. Z1 PH REACH (Zone-1 Phase Impedance Reach) This is the setting for the phase distance function, which determines the maximum distance from the relay location that phase faults may occur and produce operation of that element. It is set in positive sequence secondary ohms. For a Zone 1 function, the reach is typically set for 90% of the line length. For example, a line having a total impedance of 14 ohms, a CT ratio of 1200:5 and a VT ratio of 1000:1 would have a secondary ohmic value of ZS = ZP RC/RV = 14(240/1000) = A setting of 0.9 (3.36) = 3.02 ohms may be used. For the phase element, the accuracy of the positive sequence impedance data and the instrument transformers may allow a Zone 1 reach as high as 95%. The range of settings is 0.03 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 in 0.05 ohm increments for 1 A CT inputs. Note that the very low impedance settings, while available, may not be usable. Extremely large current is required for a fault at the balance point (depending on the source/line impedance ratio) when very low settings are used. Z1 GND TRIP (Zone-1 Ground Trip) The ground distance measuring units operate and execute appropriate protection or programmable logic, however, tripping can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. Z1 GND REACH (Zone-1 Ground Reach Impedance) This is the setting for the ground distance function which determines the maximum distance from the relay location on the protected line that ground faults may occur and produce operation of that element. It is set in positive sequence secondary ohms. This reach setting may be the same as the phase reach previously described. The K0 magnitude and angle takes into consideration the influence of the line zero sequence impedance on the apparent distance to the fault. The range of settings for Z1 is 0.03 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. Note that the very low impedance settings, while available, may not be usable. Extremely large current is required for a fault at the balance point (depending on the source to line impedance ratio) when very low settings are used. Also the maximum setting is limited by K0. The maximum accurate reach is 36/(1+K0/3) for 5 A or 180/(1+K0/3) for 1 A. Beyond this value the unit will begin to underreach by more than 5%. Settings and Application 4-7

72 Z1 GND BULLET (Zone-1 Ground Bullet) This setting enables the Zone-1 quadrilateral impedance unit. The quadrilateral unit s reach in the reactance direction is the Z1 GND REACH setting times the sine of the Z1 LINE ANG setting. The reach in the resistance direction is defined by the Z1 RESISTANCE setting below. Z1 RESISTANCE (Zone-1 Quadrilateral Unit Resistance Reach) This setting sets the resistive reach of the ground quadrilateral unit. It should be set to a maximum of 4 times Z1 GND REACH up to 80% of the minimum phase load impedance. Z1 RESISTANCE = 4 x Z1 GND REACH up to 0.8 x Real{V LN /I LM } V LN = Normal system minimum line to ground voltage I LM = Maximum phase load current The resistance reach is not zero sequence compensated and therefore operation of the non-faulted phase units may result due to the resistance setting being larger than the load impedance. To have security against overreaching trips during two-phase-to ground faults select Forward Pilot Zone settings such that PHG SEL FACT x FWP GND REACH = 22. To increase the sensitivity to internal high impedance ground faults for pilot applications, it is recommended to use directional ground overcurrent (MEDIUM SET GND TRIP = ENABLED) pilot tripping instead of the quadrilateral characteristic. Z1 OS BLOCK (Zone-1 Out-of-Step Block) Choosing the ENABLE setting will activate this function. This allows the out-of-step block logic to inhibit operation of the Zone 1 phase element during system swings or out-of-step conditions. If out-ofstep tripping (by other logic) is to be used, the blocking of Zone 1 may be enabled. If not, blocking of tripping may be DISABLE. This would allow Zone 1 phase to trip for out-of-step conditions. If this latter option is selected, the ability of the controlled circuit breakers to interrupt for out-of-phase conditions should be investigated. Z1 RECL INIT (Zone-1 Reclose Initiate) High speed reclosing, to be successful, must occur following high speed simultaneous tripping of the breakers at each end of the transmission line. Zone 1 tripping may be allowed to initiate high speed reclosing by selecting HIGH SPEED. Time delayed reclosing is usually applied with time delayed tripping, but may be desired for the application. Choosing HIGH SPEED or TIME DELAY allows further choices regarding the types of faults for which high speed or time delayed reclosing is desired. By selecting DISABLE, all high speed and time delayed reclosing is prohibited, except as governed by other elements. Z1 RI FLT TYPE (Zone-1 Reclose Initiate Fault Type) To limit reclosing to only those cases involving phase-to-ground faults (for which the impact on nearby generators is limited), select PH-GND. To allow reclosing for both phase-to-ground and phase-tophase faults, select PH-GND/PH-PH. To allow high-speed reclosing for all faults for which Zone 1 operates, select ALL FAULTS. If time delayed reclosing is selected ALL FAULTS is usually appropriate. 4-8 Settings and Application

73 Z1 TD FAULTS (Zone-1 Time Delayed Faults) This setting applies to applications where Z1 RECL INIT is selected as HIGH SPEED and Z1 RI FAULT TYPE is other than ALL FAULTS. If it is desired to time delay reclose for fault types not selected for high speed reclosing, then this setting should be ENABLE. Zone-2 Zone-2 describes setting of a distance relay which allows it to detect all faults on the entire protected transmission line plus a pre-selected area beyond the next bus in the forward direction. Z2 K0 MAG (Zone-2 Zero Sequence Compensation Magnitude) Similar to the K0 setting for Zone 1, this factor is chosen to compensate for the influence of zero sequence current on the apparent impedance seen by the ground distance unit for faults on the line. The same magnitude K0 that was chosen for Zone 1 may be used for Zone 2, unless the protected circuit is not homogeneous and a different (Z0L-Z1L)/Z1L for the total line is calculated to be different from the Zone 1 value. The magnitude of K0 may be selected in the range of 0 to 10 in increments of Z2 K0 ANG (Zone-2 Zero Sequence Compensation Angle) The angle of the total quantity (Z0L-Z1L)/Z1L may be selected in the range of -120 to +40 degrees in 1 degree increments. Z2 LINE ANG (Zone-2 Line Angle) This is the angle of the positive sequence impedance of the total protected circuit. The range of settings is 10 to 90 degrees in 1 degree increments. Z2 PH TRIP (Zone-2 Phase Trip) The phase distance measuring units operate and execute appropriate protection or programmable logic, however, tripping can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. Z2 PH REACH (Zone-2 Phase Impedance Reach) This is the setting for the Zone 2 phase distance function which must reach the most remote multiple phase fault on the protected line plus providing remote backup for devices at the next station. While very large settings are desired in the interest of providing as much coverage as possible, even with the reach shortening effect of remote-end infeed, the Zone 2 phase unit cannot be allowed to overreach any Zone 1 relay protecting other circuits connected to the remote bus. To deviate from this rule is to face the formidable task of coordinating phase and ground time delays on adjacent transmission lines. Zone 2 phase reach should be set to Z1 + Z1A where Z, is the total positive sequence impedance of the line and Z1A is the apparent impedance, with minimum infeed, of the line having the shortest Zone 1 setting for a fault at the end of that Zone 1. The range of Zone 2 phase magnitude settings is 0.03 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. Settings and Application 4-9

74 Z2 PH DLY (Zone-2 Phase Time Delay) A time delay to permit clearing of faults on or beyond the next bus. Zone-1 relays at that next bus must be allowed to operate and to initiate tripping of the breakers required to clear the fault. If the relays or breakers fail to perform that function, dependence for clearing such faults may fall to the Zone 2 relay. The time delay required for Zone 2 tripping is dependent on the relative operating times of Zone 2 and the remote relaying units such as Zone 1 (including any intentional Zone 1 delay) breaker clearing time and Zone 2 reset time. Selection of the phase and ground timer settings should also consider remote bus faults and remote breaker failure relay timing. Remote Zone 2 should not be allowed to trip until bus differential relays or breaker failure relays have had time to energize their lockout relays and clear the fault. With no Zone 1 delay and a 5 cycle breaker, the commonly used 15 cycle (0.25 sec) delay for Zone 2 tripping is more than adequate. Shorter times are possible with settings available from 0 to 10 seconds in 0.01 second increments. Longer times may be necessary to override remote breaker failure clearing times. Z2 GND TRIP (Zone-2 Ground Trip) The ground distance measuring units operate and execute appropriate protection or programmable logic, however, tripping can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. Z2 GND REACH (Zone-2 Ground Reach Impedance) This is the setting for the Zone 2 ground distance function which determines the maximum distance from the relay location that ground faults may be recognized. It is set in positive sequence ohms. It must reach the most remote ground fault on the protected line plus providing remote backup for devices at the next station. The same restrictions in reach that apply to Zone 2 phase distance settings also apply to Zone 2 ground. The Zone 2 ground unit cannot be allowed to overreach any Zone 1 unit protecting other circuits connected to the remote bus. Zone 2 ground reach should be set to Z1 + Z1A where Z1 is the total positive sequence impedance of the line and Z1A is the apparent impedance with minimum infeed, of the line having the shortest Zone 1 setting, for a fault at the end of that Zone 1. Note that the effect of zero sequence as well as positive sequence infeed current must be considered. In general a Zone 2 ground reach setting may be conservatively chosen to be the line impedance plus 50% of the impedance of the shortest line off of the next bus. Settings are available between 0.3 and 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. Also, the maximum Zone-2 setting is limited by K0. The maximum accurate reach is 36/ (1+K0/3) for 5A or 180/(1+K0/3) for 1 A. Beyond this value the unit will begin to underreach by more than 5%. Z2 GND DLY (Zone-2 Ground Time Delay) A ground delay is required for the same reasons that were outlined for the phase delay setting. Coordination is required with several remote devices: delayed Zone 1, bus relays and breaker failure clearing time. In general the commonly used 15 cycle (0.25 sec) time setting may be used, but the range of settings of 0 to 10 seconds with 0.01 increments allows higher settings if required. Z2 OS BLOCK (Zone-2 Out-of-Step Block) Choosing the ENABLE setting will activate this function. This allows the out-of-step block logic to inhibit operation of the Zone 2 phase element during system swings or out-of-step conditions. If out-ofstep tripping (by other logic) is to be used, the blocking of Zone 2 may be enabled. If not, blocking of tripping may be DISABLE. This would allow Zone 2 phase to trip for out-of-step conditions. If this latter option is selected, the ability of the controlled circuit breakers to interrupt for out-of-phase conditions should be investigated Settings and Application

75 Z2 RECL INIT (Zone-2 Time Delayed Reclose Initiate) There are two outputs for reclose initiate functions. One for high speed reclose initiate and the other for a time delayed reclose initiate. Usually high speed tripping functions...high set overcurrent, Zone-1 and pilot, provide a high speed reclose initiates where synchro-checking is normally not required for reclosing. Time delayed tripping functions...zone-2, Zone-3 and time delayed overcurrent issue a time delayed reclose initiate where synchro-checking is required. Choosing ENABLE to permit time delayed reclosing on all faults. By selecting DISABLE, all time delayed reclosing is prohibited, except as governed by other elements. Zone-3 Zone-3 describes the setting of a distance relay which allows a reach setting to be greater than the Zone 2 setting. Zone-3 ground units are also used to detect two phase-to-ground faults and block Zone-1 and forward pilot single phase-to-ground tripping. The Zone-3 phase and ground reach settings should be 150% of the forward pilot zone reach setting. Z3 K0 MAG (Zone-3 Zero Sequence Compensation Magnitude) Similar to the K0 setting for Zone 2, this factor is chosen to compensate for the influence of zero sequence current on the apparent impedance seen by the ground distance for faults in the selected direction. Normally, the same K0 used for Zone 2 is used, if the lines off of the next forward bus are quite dissimilar from the protected line, K0 may be modified to reflect that difference. The magnitude of K0 may be selected in the range of 0 to 10 in increments of Z3 K0 ANG (Zone-3 Zero Sequence Compensation Angle) The angle of the total quantity (Z0L - Z1L)/Z1L may be selected in the range of -120 to +40 degrees in 1 degree increments. Z3 LINE ANG (Zone-3 Line Angle) This is the angle of the positive sequence impedance of the total circuit protected by the Zone 3 element. It is not a critical setting and a reasonable compromise is to use the protected line angle. For faults external to the protected line, infeed effect from out of phase generation will generally prevent possible refinement of this angle. The range of setting is 10 to 90 degrees in 1 degree increments. Z3 PH TRIP (Zone-3 Phase Trip) The phase distance measuring units operate and execute appropriate protection or programmable logic, however, tripping can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. Z3 PH REACH (Zone-3 Phase Impedance Reach) This is the setting for the Zone 3 forward phase distance function. The Zone 3 relay is generally set farther than the Zone 2 phase distance function. Blinder supervision eliminates the restriction imposed on reach by load. The actual reach is obscured by the infeed effect of other circuits connected to the bus at the end of the protected line. The range of the Zone 3 phase reach settings is 0.03 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. Settings and Application 4-11

76 Z3 PH DLY (Zone-3 Phase Time Delay) A time delay to permit other phase elements to operate, if possible, thus producing a minimum outage area for faults. Zone 3 setting must be time-coordinated with the Zone 2 phase delay. With 0.25 second Zone 2 phase delay, 0.5 second Zone 3 phase delay is generally adequate to allow Zone 2 to trip through its phase delay and to have the circuit breaker clear the fault before Zone 3 phase delay can time out. Z3 GND TRIP (Zone-3 Ground Trip) The ground distance measuring units operate and execute appropriate protection or programmable logic, however, tripping can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. Z3 GND REACH (Zone-3 Ground Reach Impedance) This is the setting for the Zone 3 distance function which determines the maximum distance from the relay location that ground faults may be recognized. It is set in positive sequence ohms. The Zone 3 ground distance element should be set farther than the Zone 2 and forward pilot ground distance zones, preferably to reach the end of the longest line off of the next forward bus. The actual reach is obscured by the infeed effect of other circuits connected to the bus at the end of the protected line. The range of the Zone 3 ground reach settings is 0.03 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. The maximum Zone-3 setting is limited by K0. The maximum accurate reach is 36/(1+K0/3) for 5 A or 180/(1+K0/3) for 1A. Beyond this value the unit will begin to underreach by more than 5%. Z3 GND DLY (Zone-3 Ground Time Delay) The same principles described for Zone 3 phase delay apply as well to Zone 3 ground delay. 0.5 second phase delay is generally suitable to coordinate with Zone 2 ground. Z3 OS BLOCK (Zone-3 Out-of-Step Block) Each zone may be independently blocked, as selected, when an out-of-step or power system swing condition is detected. The function may be activated for Zone 3 by choosing the ENABLE setting. This allows the out-of-step block logic to inhibit operation of the Zone 3 phase element. Large reach setting suggests OS block should be enabled. However the long time setting provides considerable security, and Zone 3 time tripping is a last backup function and some prefer not to block it. Z3 RECL INIT (Zone-3 Time Delayed Reclose Initiate) The initiation of reclosing by the time delayed Zone 3 tripping for all fault types may be selected by choosing ENABLE for this setting. Due to the multiple contingency nature of any Zone 3 operation, reclosing is not generally recommended and the setting should be DISABLE. Forward Pilot Zone Pilot is a designation applied to relaying systems which utilize a communication system between the two or more transmission line terminals. This gives the local terminal, information regarding the status of elements at each remote terminal. The REL 500 Series provides independent phase and ground pilot zones for pilot applications. For non-pilot applications these zones elements are available for other user defined applications using programmable logic. The reach of the pilot zones also controls the reach of the fault recording function Settings and Application

77 FWP K0 MAG (Forward Pilot Zero Sequence Compensation Magnitude) Similar to the K0 setting for Zone 1, this factor is chosen to compensate for the influence of zero sequence current on the apparent impedance seen by the ground distance unit for faults on the line. The same magnitude K0 that was chosen for Zone 1 may be used for forward pilot ground, unless the protected circuit is not homogeneous and a different (Z0L-Z1L)/Z1L for the total line is calculated to be different from the Zone 1 value. The magnitude of K0 may be selected in the range of 0 to 10 in increments of FWP K0 ANG (Forward Pilot Zero Sequence Compensation Angle) The angle of the total quality (Z0L-Z1L)/Z1L may be selected in the range of -120 to +40 degrees in 1 degree increments. FWP LINE ANG (Forward Pilot Line Angle) This is the angle of the positive sequence impedance of the total protected circuit. The range of settings is 10 to 90 degrees in 1 degree increments. FWP PH TRIP (Forward Pilot Phase Trip) The phase distance measuring units operate and execute appropriate protection, pilot or programmable logic, however, tripping by the unit (without pilot) can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. FWP PH REACH (Forward Pilot Phase Impedance Reach) This is the setting for the pilot phase distance function which must reach the most remote multiple phase fault on the protected line. For pilot applications the forward pilot phase reach may be set without concern for coordinating with other devices. Contrary to the limitations of the Zone 2 forward reach, no such limits exists for the pilot phase element. To insure fast pilot operation the forward pilot phase reach should be set such that the SIR (source impedance to forward pilot reach setting ratio) is less than 5.0. In general the reach is set at 150% of the line positive sequence impedance. This may be done without concern of overreaching adjacent line Zone 1 phase elements. Also it need not consider maximum load conditions because of the inclusion of a selectable blinder load restriction function. It is set in positive sequence ohms. The range of pilot phase magnitude settings is 0.03 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. Using this zone for non-pilot tripping may require coordination with the other zone impedance reach elements. One such application would be to use the forward pilot zone to enhance Zone-2 coverage for some three terminal line applications where Zone-2 setting, limited by an adjacent short line connected to a remote bus, cannot overreach the other remote bus. Both the reach and time delay must be carefully coordinated with Zones 2 and 3. FWP PH DLY (Forward Pilot Phase Time Delay) This function complements the Z2 PH DLY function as discussed above. Unless there is a special need this unit would normally be set to DISABLE. DISABLE prevents direct time delayed tripping with the forward pilot zone, but still allows it to work with all pilot functions. Settings and Application 4-13

78 FWP GND TRIP (Forward Pilot Ground Trip) The ground distance measuring units operate and execute appropriate protection, pilot or programmable logic, however, tripping by the unit (without pilot) can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. FWP GND REACH (Forward Pilot Ground Impedance Reach) This is the setting for the pilot ground distance function which determines the maximum distance from the relay location that ground faults may be recognized. It is set in positive sequence ohms. It must reach the most remote ground fault on the protected line. Parallel lines, having zero sequence contributions to remote ground faults have a reach-shortening effect on ground distance relays. The pilot ground element must cover the entire protected line even though a parallel line has a substantial zero sequence mutual effect and is contributing in the same direction to the fault. To assure total line coverage, in spite of this detrimental effect, it may be necessary to use a setting of as much as 160% of the total line impedance. Additionally, as with the phase reach, the reach should be set to assure a SIR less than 5.0. Settings are available between 0.03 and 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. The maximum forward pilot zone setting is limited by K0. The maximum accurate reach is 36/(1+K0/3) for 5A or 180/(1+K0/3) for 1 A. Beyond this value the unit will begin to underreach by more than 5%. This element with its timer may also be used for time delayed tripping. FWP GND DLY (Forward Pilot Ground Time Delay) The same principles described for the forward pilot phase delay apply as well to forward pilot ground delay. FWP OS BLK (Forward Pilot Out-of-Step Block) Each zone may be independently blocked, as selected, when an out-of-step or swing condition is detected. This function may be activated for FORWARD PILOT by choosing the ENABLE setting. This allows the out-of-step block logic to inhibit operation of the pilot 3-phase elements during system swings or out-of-step conditions. Because of the large setting of the forward pilot phase element, it is advisable to ENABLE this function. Blinder (inner) supervision may be enabled (under the OUT-OF- STEP group of settings) for the pilot 3-phase element, even though OUT-OF-STEP blocking is disabled. Reverse Pilot Zone This is a function that serves as a supplement to the forward pilot relaying. Its logic is very much dependent on the chosen pilot system type. When used with a BLOCKING scheme, it serves as a carrier start function to complement the overcurrent carrier start. Coordination is required between the local reverse pilot settings and the remote forward pilot settings to assure that all external faults within the reach of the forward pilot element will be recognized by the reverse pilot element to cause channel keying to prevent tripping. In POTT (permissive overreaching transfer trip) or unblocking applications, the reverse pilot element serves the purpose of controlling the transient blocking function to avoid undesired tripping for faults on adjacent lines for which sequential clearing occurs. Reverse pilot prevents echo keying for reverse faults, and also prevents weakfeed tripping for external faults. This zone is also available for backup tripping functions or other user programmed applications for both pilot and non-pilot applications. Also, the reach of the pilot zones also controls the reach of the fault recording function Settings and Application

79 RVP K0 MAG (Revere Pilot Zero Sequence Compensation Factor Magnitude) The same setting used for FWP K0 MAG should be used for reverse pilot. For through faults it is imperative that the two systems respond in the same way. RVP K0 ANG (Reverse Pilot Zero Sequence Compensation Angle) The same setting used for FWP K0 ANG angle should be used for reverse pilot. RVP LINE ANG (Reverse Pilot Line Angle) The same setting used for FWP LINE ANG should be used for reverse pilot. RVP PH TRIP (Reverse Pilot Phase Trip) The phase distance measuring units operate and execute appropriate protection, pilot or programmable logic, however, tripping by the unit can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. RVP PH REACH (Reverse Pilot Phase Impedance Reach) When using the BLOCKING system type, this setting must be chosen carefully to assure that all external faults which can be recognized by the remote forward pilot element will be recognized by this local REVERSE PILOT element. In general, a reach setting of 50-70% of the setting of the remote FWP PH REACH will be adequate. The range of settings available is 0.03 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 0.15 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. In the POTT and UNBLOCK systems, weakfeed trip is based upon undervoltage and no reverse element operation. For tripping to occur, the remote FORWARD PILOT elements must operate. To assure compatibility between the undervoltage and the REVERSE PILOT action, the REVERSE PILOT relay must recognize all external faults that can be detected by the remote FORWARD PILOT elements. By using the same setting strategy for POTT and UNBLOCK, REVERSE PILOT as is recommended for the BLOCKING scheme, security will be assured. If the PUTT (permissive underreaching transfer-trip) pilot system type is chosen the REVERSE PILOT function serves no useful purpose, and the distance functions may be set for zero reach. RVP PH DLY (Reverse Pilot Phase Time Delay) The reverse pilot zone may be used to provide backup protection for bus faults. The phase delay should exceed the 87B plus 86B plus breaker time plus margin. A setting as low as 0.17 seconds may be possible, thus preventing remote Zone 2 relays from operating for backup bus tripping by the reverse pilot element. RVP GND TRIP (Reverse Pilot Ground Trip) The ground distance measuring units operate and execute appropriate protection, pilot or programmable logic, however, tripping by the unit can be enabled or disabled. This allows the use of the units for other functions. The setting choices are ENABLE or DISABLE. RVP GND REACH (Reverse Pilot Ground Impedance Reach) A setting identical to that used for PHASE REACH may be selected. The maximum reverse ground setting is limited by K0. The maximum accurate reach is 36/(1+K0/3) or 180/(1+K0/3). Beyond this value the unit will begin to underreach by more than 5%. Settings and Application 4-15

80 RVP GND DLY (Reverse Pilot Ground Time Delay) The same principles described for the forward pilot phase delay apply as well to reverse pilot ground delay. Line Characteristics LN LGTH UNITS (Line Length Units) This setting defines the units of length, as miles or kilometers, that will be displayed for the distance to fault on the UI and in the target record. LN R PU (Resistance Per Line Length Unit) This is the resistive impedance per unit of the protected line. It is expressed in secondary ohms/mile or ohms/kilometer. This value is used in fault location calculations. LN X PU (Reactance Per Line Length Unit) This is the reactive impedance per unit of the protected line. It is expressed in secondary ohms/mile or ohms/kilometer. This value is used in fault location calculations. Notes 4-16 Settings and Application

81 Out-of-Step and Load Restriction Out-of-step conditions involve the loss of synchronism of a machine or collection of machines with respect to another part of the power system. Another related phenomenon is a stable swing condition which has a similar character, but for which no instability occurs. Out-of-step conditions require that the two system segments be separated and that, possibly after load shedding, they be re-synchronized. Swing conditions produce voltages and currents within the system which may cause undesired operation of distance relaying functions. Out-of-step conditions must be corrected by tripping either through this relaying system or through another which will produce a more equitable generation load match following the separation. Stable swing conditions are self-restoring and require no tripping, but may require blocking of certain distance relaying elements. Out-of-step (unstable) and stable swing conditions are both sensed by the relative time of operation of an outer blinder sensing function and an inner blinder sensing function. Faults may cause them to operate essentially simultaneously whereas swing conditions produce sequential operation of first the outer blinder and then the inner blinder. For the REL milliseconds is the time limit for which the outer blinder must operate and the inner blinder not operate (time between points 1 and 2) to establish that the condition being observed is a swing and not a fault. Swings take a longer time than this value while faults take less. Out-of-step conditions involve a trajectory (as time passes) of ohms on the R-X (resistance-reactance) diagram (see figure below) such that the moving ohmic value enters from one side crossing the outer blinder first (point 1) and then the inner blinder (point 2), crosses the circular impedance characteristics, and departs from the other side (points 3 and 4). Once point 2 is crossed the swing is considered unstable. Stable swing conditions cause the ohmic trajectory to emerge from inside the outer blinder moving toward the direction from which it entered (from point 1 back to 5). The inner blinder is never crossed. This difference allows a distinction to be made between stable swings (recoverable) and unstable swings (unrecoverable). Figure 4-2. Out-of-Step (Power Swing) Settings and Application 4-17

82 Blinder Settings BLNDR INNER R (Inner Blinder Resistive Reach) This is the resistance setting for the inner blinder. If it is to be used for load restriction it must have a setting sufficiently low (in ohms) to avoid operation on the minimum stable swing ohms expected. Similarly it must have a setting sufficiently high to accommodate the maximum fault resistance that is likely to be encountered for 3-phase faults on the protected line. Operation of the 3-phase distance function for all zones can be avoided for swing angles (between the two equivalent sources) as great as if the inner blinder is given a resistance setting of Z T (derived from basic trig) or less, where Z T is the protected line positive sequence impedance plus the sum of the lowest positive sequence source impedances at each end of the line. The minimum setting should accommodate a 3-phase fault resistance value of at least 0.1 Z T ohms based on an arc voltage of 400 volts per foot (primary) and typical phase separation. Using the average of these two conservative figures a reasonable value to use for the inner blinder resistance setting is 0.2 Z T. The range of settings available is 1 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 5.0 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. This blinder is unrelated to the similar characteristic element which is part of the quadrilateral ground function, and therefore requires an independent setting. BLNDR OUTER R (Outer Blinder Resistive Reach) The outer blinder resistance setting must be chosen to assure proper distinction between faults and swing conditions. Based upon a severe swing rate (20 0 per cycle), the outer blinder may be set at 2.5 times the inner blinder setting, and the swing ohms will remain between blinders for at least 50 ms. This time represents approximately a 60 0 swing between blinders at 60 Hz. For faults, essentially simultaneous operation of the two blinders (four blinder lines) identifies the fact that it is a fault. For faster swings, a wider separation of the outer blinder from the inner settings is required. A 2 ohm (secondary) separation has been used historically with success. Sustained load must not be allowed to operate the outer blinder because it will block 3-phase fault tripping. The range of resistance settings available is 1.0 to 36 ohms in 0.01 ohm increments for 5 A CT inputs or 5.0 to 180 ohms in 0.05 ohm increments for 1 A CT inputs. BLNDR ANG (Blinder Angle) The blinder angle is chosen to be the same as the line angle unless some special consideration dictates otherwise. The range of settings is 0 to 90 0 in 1.0 degree increments. Out-of-Step System Type OS TYPE (Out-of-Step System Type) The options which may be selected for OS system type are OS BLK, OS TRIP and DISABLE. OS BLK allows the blocking of tripping of selectable zone, 3-phase elements following the detection of a swing (stable or unstable) condition, OS TRIP selection provides the OS BLK function and produces a trip following satisfaction of the out-of-step trip logic. DISABLE blocks the operation of the out-ofstep logic Settings and Application

83 Load Restriction LD RESTRICTION (Load Restriction) Figure 4-3. Load Restriction The Load Restriction function allows the use of the inner blinder to restrict the trip area on the R-X diagram for all of the 3-phase elements. This prevents undesired tripping due to very large loads. Load restriction should also be enabled if out-of-step blocking or tripping is enabled. This insures correct out-of-step functioning where the blinders intersect the impedance characteristics. Out-of-Step Block OS OVRD TM (Out-of-Step Override Time) The out-of-step override timer releases the out-of-step blocking or out-of-step tripping logic, depending on which is enabled, in the event an apparently slow moving impedance swing is actually an internal three phase fault. If a 3-phase fault does occur, tripping is desired immediately. On the other hand, a slow transition of swing ohms through the inner blinder area should not produce tripping through this logic, unless the protected line is jeopardized thermally. In general, a 0.4 second time setting is suitable. The range of settings available is 0.4 to 4.0 seconds in 0.01 second increments. Out-of-Step Trip OST TIME 1 (Out-of-Step Trip Time 1) The outer blinder has operated and a swing condition is established. This timer is to insure that more than a momentary operation of the inner blinder has occurred before committing to an out-of-step trip. The timer should be set for 0.02 seconds. The range of settings is 0.0 to 0.12 seconds in 0.01 second increments. Settings and Application 4-19

84 OST TIME 2 (Out-of-Step Trip Time 2) This timer insures that for tripping on the way-out that adequate time has elapsed between blinders (inner blinders reset, point 3 and outer blinders reset, point 4). The default setting is 0.02 seconds. The range of settings is 0.0 to 0.12 seconds. When the outer blinder resets, the dropout time of OS TRP TM 2 prevails for a short period. When BOS, the supervised outer blinder resets, a trip period is established after 20 ms for 500 ms of out-of-step tripping. OST RESET TIME (Out-of-Step Trip Reset Time) This is the reset time associated with OS TRP TM1 and OS TRP TM2. It must persist for a period of time sufficiently long to commit the 20/500 ms timer to operation for way-out tripping. The recommended setting is 0.05 seconds. The range of times available is 0.0 to 0.16 seconds in 0.01 second increments. OST, WAY IN/OUT (Out-of-Step Tripping on the Way In or Way Out) Tripping for out-of-step conditions may be selected to occur on the way in as the swing ohms progress into the trip area of the inner blinder (point 2) or on the way out as it departs from the trip area of the outer blinder (point 4). The choice is dictated by the swing rate expected. Tripping on the way-out produces a much softer impact on the circuit breaker involved because of the more favorable transient recovery voltage that results from tripping at a smaller angle between the two system segments that must be separated because of loss of synchronism. Tripping on the way-in is reserved for the massive systems whose angular movement with respect to one another is very slow during separation. There is a real danger that transmission line thermal damage may occur if tripping is delayed until a more favorable angle is reached. In general, choose tripping on the WAY-OUT where the swing rate is expected to be sufficiently fast, such that no transmission line thermal problems will result in the process. Otherwise choose WAY- IN. OS OVRD TM (Out-of-Step Override Time) The out-of-step override timer is the same timer discussed in the Out-of-Step Block Section above. Instantaneous Overcurrent Elements (Type 50) High Set Overcurrent Elements and Functions HS 50P PU (High Set Phase Overcurrent Pickup) 50H This setting sets the pickup current value for the high set phase overcurrent unit. The unit can be set to pickup from 2 to 100 amps in 0.1 amp increments for 5 A CT inputs or from 0.4 to 20 amps in 0.02 amp increments. HS 50P TRP (High Set Phase Overcurrent Trip) 50H This setting enables tripping with the high set phase overcurrent unit. High speed tripping with the high set phase overcurrent unit is permitted for close proximity faults well within the Zone-1 reach. The optimum use of highset trip is to coordinate tripping for remote faults. In a networked system it is desirable not to trip for faults at the remote bus and trip for line end faults at the remote when the remote breaker is open. This ability depends on the system configuration, fault current levels and the margin between them. The 50H units are set by coordinating three phase fault currents. The settings are ENABLE or DISABLE. Additional settings associated with the high set phase overcurrent unit are: 4-20 Settings and Application

85 HS 50P DIR This setting enables forward directional supervision of the high set phase overcurrent unit. To confine tripping to line faults only, it is normally recommended to set the high set unit to be directionally supervised. Directionality may be inherent with strong reverse sources and therefore it may be preferred that the directional setting not be used in order to have improved tripping dependability. The settings are ENABLE or DISABLE. HS 50N PU (High Set Ground Overcurrent Pickup) 50NH This setting sets the pickup current value for the high set ground overcurrent unit. This unit measures the residual ground current 3I 0. The unit can be set to pickup from 2 to 100 amps in 0.1 amp increments for 5A CT inputs or from 0.4 to 20 amps for 1A CT inputs. HS 50N TRP (High Set Ground Overcurrent Trip) 50NH This setting enables tripping with the high set ground overcurrent unit. High speed tripping with the high set ground overcurrent unit is desirable for close proximity faults well within the Zone-1 reach. The optimum use of high set trip is to coordinate tripping for remote faults. In a networked system it is desirable not to trip for faults at the remote bus and trip for line end faults at the remote when the remote breaker is open. This ability depends on the system configuration, fault current levels and the margin between them. The 50NH units are set by coordinating single phase-to-ground fault currents. The settings are ENABLE or DISABLE. Additional settings associated with the high set ground overcurrent unit are: HS 50N DIR This setting enables directional supervision of the high ground overcurrent unit. To confine tripping to line faults only, it is normally recommended to set the high set unit to be directionally supervised. Directionality may be inherent with strong reverse sources and therefore it may be preferred that the directional setting not be used in order to have improved tripping dependability. The settings are EN- ABLE or DISABLE. HS 50Q PU (High Set Negative Sequence Overcurrent Pickup) 50QH This setting sets the pickup current value for the high set negative sequence overcurrent unit. This unit measures 3I 2. The unit can be set to pickup from 2 to 100 amps in 0.1 amp increments for 5 A CT inputs or from 0.4 to 20 amps in 0.02 amp increments for 1 A CT inputs. HS 50Q TRP (High Set Negative Sequence Overcurrent Trip) 50QH This setting enables tripping with the high set negative sequence overcurrent unit. Large negative sequence currents are produced as a result of phase-to-phase faults. High speed tripping for these faults is desirable for close proximity faults well within the Zone-1 reach. The optimum use of highset trip is to coordinate tripping for remote faults. In a networked system it is desirable not to trip for faults at the remote bus and trip for line end faults at the remote when the remote breaker is open. This ability depends on the system configuration, fault current levels and the margin between them. The 50QH units are set by coordinating phase-to-phase fault currents. The settings are ENABLE or DIS- ABLE. Additional settings associated with the high set ground overcurrent unit are: HS 50Q DIR This setting enables directional supervision of the high I2 overcurrent unit. To confine tripping to line faults only, it is normally recommended to set the high set unit to be directionally supervised. Directionality may be inherent with strong reverse sources and therefore it may be preferred that the directional setting not be used in order to have improved tripping dependability. The settings are ENABLE or DISABLE. Settings and Application 4-21

86 HS 50 RI (High Set Overcurrent Reclose Initiate) High speed reclosing, to be successful, must occur following high speed simultaneous tripping of the breakers at each end of the transmission line. High set overcurrent tripping may be allowed to initiate high speed reclosing by selecting HIGH SPEED. Time delayed reclosing is usually applied with time delayed tripping, but may be desired depending on the application. Choosing HIGH SPEED or TIME DELAY allows further choices regarding the types of faults for which high speed or time delayed reclosing is desired. By selecting DISABLE, all high speed and time delayed reclosing is prohibited, except as governed by other elements. HS RI FAULT TYPE (Reclose Initiate Fault Type) To limit reclosing to only those cases involving phase-to-ground faults (for which the impact on nearby generators is limited), select PH-GND. To allow reclosing for both phase-to-ground and phase-tophase faults, select PH-GND/PH-PH. To allow reclosing for all faults for which the high set overcurrent element operates, select ALL FAULTS. If time delayed reclosing is selected ALL FAULTS is usually appropriate. HS TD FAULTS (High Set Overcurrent Time Delayed Faults) This setting applies to where HS 50RI is selected as HIGH SPEED and HS RI FAULT TYPE is other than ALL FAULTS. If it is desired to time delay reclose fro fault types not selected for high speed reclosing then this setting should be ENABLE. Medium Set Overcurrent Elements and Functions MS 50P PU (Medium Set Phase Overcurrent Pickup) 50M The medium set phase overcurrent supervises the inner and outer blinder units for the out of step logic, and the phase distance units enabling them to operate if the setting value is reached. The setting range is 0.5 to 12 amps with 0.1 amp increments for 5 A CT inputs or 0.1 to 2.4 with 0.02 amp increments for 1 A CT inputs. The setting should be set as low as possible, influenced only by the maximum load current and minimum phase-to-phase fault current. Phase-to-phase fault current must be above the setting value and within the protecting zone before tripping is allowed. This unit is also used in the single pole tripping logic if applied. MS 50N PU (Medium Set Ground Overcurrent Pickup) 50NM The medium set ground pickup current, 50NM, is always forward directional and used in the single pole trip, loss of current and pilot logic and time delayed directional overcurrent tripping. This unit measures 3I 0. The setting range is 0.5 to 12 amps with 0.1 amp increments for 5 A CT inputs or 0.1 to 2.4 with 0.02 amp increments for 1 A CT inputs. The setting should be as low as possible and is influenced by the maximum ground current (3I 0 ) which may exist with unbalanced loads or during transient switching operations which influence line current for periods long enough for relay tripping to occur (usually load break switches or breakers with pole spans greater than 8 ms). Ground current coordination with the remote terminal for blocking pilot schemes is also required. Single phase to ground fault current must be above the setting before tripping of the ground distance units is permitted. For blocking pilot schemes, 50NM must coordinate with and not overreach the reverse directional supervised low set ground pickup current, 50NL, at the remote terminal. Maximum sensitivity is desired for detection of high resistance ground faults and a setting ratio (med set local/ low set remote) of 2 is normally recommended Settings and Application

87 MS 50N TRP (Medium Set Ground Overcurrent Trip) 50NM For step distance applications, definite time overcurrent backup protection is achieved by enabling the forward directional medium set overcurrent ground trip. The trip time must be set with the medium set ground time delay, MS 50N DLY, and be coordinated with remote terminals. For Pilot applications, enabling the medium set overcurrent also requires that a setting be chosen for the medium set ground delay timer. This time setting delays the directional overcurrent element long enough to allow the ground distance unit to control the channel and overreaching pilot tripping if it is able to operate. If the fault resistance is too high for the ground distance element and above the setting of 50NM (and within the sensitivity limit for ground directional sensing) normal pilot tripping will result for internal faults. A delay of 0.05 seconds is suggested for normal applications. Where zero sequence mutual problems exist and an overreaching pilot system is selected choose DISABLE to avoid a possible false trip, or use negative sequence for the ground directional element. MS 50N DLY Sets the trip time for the medium set ground trip function if selected. The range of settings for the timer is 0 to 10.0 in 0.01 seconds increments. MS 50Q PU (Medium Set Negative Sequence Overcurrent Pickup) 50QM The medium set negative sequence pickup current, 50QM, is always forward directional. This unit measures 3I 2. The setting range is 0.25 to 20 amps with 0.1 amp increments for 5 A CT inputs or 0.05 to 4.0 with 0.02 amp increments for 1 A CT inputs. The setting should be set as low as possible and is influenced by the maximum negative sequence current which may exist under normal operating conditions... non-transposed lines, unbalanced loads, transient switching operations which influence line current for periods long enough for relay tripping to occur (usually load break switches or breakers with pole spans greater than 8 ms). MS 50Q TRP (Medium Set Negative Sequence Overcurrent Trip) 50QM Definite time I 2 overcurrent backup protection is achieved by enabling the forward directional medium set I 2 overcurrent trip. The trip time must be set with the medium set I 2 time delay, MS 50Q DLY, and be coordinated with remote terminals. MS 50Q DLY Sets the trip time for the medium set I 2 trip function if selected. The range of settings for the timer is 0 to 10.0 in 0.01 seconds increments. Low Set Overcurrent Elements and Functions LS 50P PU (Low Set Phase Overcurrent Pickup) 50L The low set phase pickup current is used in the close into fault trip and load loss accelerated trip logic. The setting range is 0.25 to 20 amps with 0.1 amp increments for 5 A CT inputs or 0.05 to 4.0 with 0.02 amp increments for 1 A CT inputs. The relay looks for current above the line charging current and no voltage to detect a close into fault condition. Therefore, the setting should always be above protected line s charging current. The charging current increases with the line length and a setting of 0.5 A is usually sufficient except for very long lines. For load loss accelerated trip, the relay looks for the loss of balanced load current due to the remote line breaker clearing of an end zone (Zone-2 region of the local breaker) fault. When this condition is detected the Zone-2 timer is bypassed for accelerated Zone-2 tripping. The low set phase pickup for this application must be greater than the maximum tapped load on the protected line. If there are no tapped loads, a setting of 0.5 A is generally adequate. Settings and Application 4-23

88 LS 50N PU (Low Set Ground Overcurrent Pickup) 50NL The low set ground current, 50NL, is used in the close into fault trip, out of step, loss of potential and pilot logic. The setting range is 0.5 to 12 amps with 0.1 amp increments for 5 A CT inputs or 0.1 to 2.4 with 0.02 amp increments for 1 A CT inputs. The loss of potential logic (blown fuse, open phase, etc.) will be blocked to allow tripping if 50NL is true. The relay also looks for 50NL and no voltage to detect a close into fault condition. For blocking pilot applications, 50NL is directionally supervised in the reverse direction and must be coordinated with and overreach the forward looking medium set ground pickup current, 50NM, at the remote terminal. LS 50Q PU (Low Set Negative Sequence Overcurrent) 50QL There is no setting as the 50QL is provided with a fixed threshold of 0.5 A (.1 for 1A CT). This unit measures 3I2. The low set negative sequence 50QL current and low set ground 50NL current indicate the presence of a fault and therefore block out-of-step operation. Inverse Time Overcurrent Elements (Type 51) Time Overcurrent Characteristics ANSI/IEEE The characteristic equation for the time overcurrent operate and reset characteristics based on the proposed IEEE Standard PC are: t(i) = [A/(M p - 1) + B]td/5 M > 1 (operate) t = [tr/(m 2-1)]td/5 0 < M < 1 (reset) where: t(i) = time to operation for the input current I A = A constant (ie. 51P BU A VALUE) I = input current M = I/I pu (ie. for I = 5 x 51N BU PICKUP, M = 5) p = p constant (ie. 51N Z2 p VALUE) B = B constant (ie. 51P BU B VALUE) td = time dial (ie. 51N BU TIME DIAL) tr = reset time for I= 0 as determined by test on the CO family The expression, td/5, is a modification to the IEEE equations to account for different time dial settings. This follows the desired intent of time dials and that is that the time dial setting of 2n will result in an operating time two times that of a time dial setting of n for a given current. The constants A, B, p, and tr are determined for a curve near the middle of the time dial range. In the case of the CO family, time dial 5, is very near the middle setting for the range 0.5 to For other curve families the constants should be determined for the time dial nearest the center of the family range, td m. then the td setting (ie. 51P BU TIME DIAL) would be: td = (desired family time dial/td m )5 For example: The MCO curves have a time dial range of time dial curves from 3 to 63. Time dial 30 would be selected as the median and p, A, and B would be computed from it and entered as settings. If you wanted to use the MCO time dial 15 characteristic you would compute td = (15/30)5 and enter 2.5 as the time dial setting. If you determine the constants directly from a specifically desired curve then the td setting should be Settings and Application

89 Table 4-1 shows the appropriate constants which provide a close emulation of the CO family characteristics. Figure 4-4. Inverse Time Overcurrent Characteristics Table 4-1. Type CO Induction Relay Family Models Curve Type CO A B p tr (sec.) Short Time CO Long Time CO Definite Time CO Moderately Inverse CO Inverse CO Very Inverse CO Extremely Inverse CO Test error can be minimized when comparing test results with computed test points by subtracting from the B value of the table when setting the relay, but comparing with the test points computed with the values in the table. Settings and Application 4-25

90 IEC A very similar equation is used in IEC markets. t(i) = K/(M p - 1) tm M > 1 (operate) where: K = A constant (ie. 51P BU A VALUE) as defined above, and tm = time multiple. The time dial setting (ie. 51N BU TIME DIAL) is the time multiple times 5 (td = tm*5). Also, the b constant (ie. 51P BU B VALUE) is set to zero. Time Overcurrent Elements TD 51P (51 Phase Time Overcurrent Backup) 51P This setting enables backup tripping with the phase time overcurrent element providing additional protection to remote terminals. The element can be (torque) controlled by directional or Zone-2 elements to provide greater application flexibility. Additional settings associated with the time overcurrent phase element are: TD 51P PU This setting sets the pickup current value for the phase overcurrent element. The setting range is 0.5 to 12 amps with 0.1 amp increments for 5 A CT inputs or 0.1 to 2.4 with 0.02 amp increments for 1 A CT inputs. TD 51P A VALUE, TD 51P B VALUE, TD 51P P VALUE, TD 51P TM DIAL These settings define the inverse time vs. current characteristics of the time overcurrent curve defined by the equation t(i) = [A/(M p - 1) + B]td/5. TD 51P TR VALUE This setting defines the reset time characteristics of the 51P element with the equation t = [tr/(m 2-1)]td/5. TD 51P CONTROL A (torque) control function differs from a supervision function initiate the controlling element must operate to enable the controlled element to begin operation. This insures secure operation. This setting defines the controlling element of the 51P element as either none, forward directional phase, reverse directional phase, or Zone-2 phase. TD 51N (51 Ground Overcurrent Backup) 51N This setting enables backup tripping with the ground time overcurrent element providing additional protection to remote terminals. The element can be (torque) controlled by directional or Zone-2 elements to provide greater application flexibility. Additional settings associated with the time overcurrent ground element are: TD 51N PU This setting sets the pickup current value for the ground time overcurrent element. The setting range is 0.5 to 12 amps with 0.1 amp increments for 5 A CT inputs or 0.1 to 2.4 with 0.02 amp increments for 1 A CT inputs Settings and Application

91 TD 51N A VALUE, TD 51N B VALUE, TD 51N P VALUE, TD 51N TM DIAL These settings define the inverse time vs. current characteristics of the time overcurrent curve defined by the equation t(i) = [A/(M p - 1) + B]td/5. TD 51N TR VALUE This setting defines the reset time characteristics of the 51N element with the equation t = [tr/(m 2-1)]td/5. TD 51N CONTROL A (torque) control function differs from a supervision function initiate the controlling element must operate to enable the controlled element to begin operation. This insures secure operation. This setting defines the controlling element of the 51N element as either none, forward directional ground, reverse directional ground, or Zone-2 ground. TD 51Q (51 Negative Sequence Overcurrent Backup) 51Q This setting enables backup tripping with the negative sequence time overcurrent element providing additional protection to remote terminals. The unit measures 3I 2. The element can be (torque) controlled by directional or Zone-2 elements to provide greater application flexibility. Additional settings associated with the 51Q unit are: TD 51Q PU This setting sets the pickup current value for the negative sequence overcurrent element. The setting range is 0.5 to 12 amps with 0.1 amp increments for 5 A CT inputs or 0.1 to 2.4 with 0.02 amp increments for 1 A CT inputs. TD 51Q A VALUE, TD 51Q B VALUE, TD 51Q P VALUE, TD 51Q TM DIAL These settings define the inverse time vs. current characteristics of the time overcurrent curve defined by the equation t(i) = [A/(M p - 1) + B]td/5. TD 51Q TR VALUE This setting defines reset time characteristics of the negative sequence element with the equation t = [tr/(m 2-1)]td/5. TD 51Q CONTROL A (torque) control function differs from a supervision function initiate the controlling element must operate to enable the controlled element to begin operation. This insures secure operation. This setting defines the controlling element of the 51Q element as either none; forward directional negative sequence, reverse directional negative sequence, or Zone-2 phase to phase. Settings and Application 4-27

92 Other Overcurrent Elements and Logic Functions CIFT (Close into Fault Trip) This setting enables the close into fault trip logic which detects fault current and a low voltage conditions upon breaker closing. Close into fault logic supplements the distance units where potential transformers on the line side of the breaker are used (current transformers are on the bus side). It is intended to detect permanent faults that may have developed on the de-energized line while the breaker was opened for an extended period...ground chains. Close into fault logic should be disabled where both current and voltage transformers are applied on the bus side. CIFT TM DLY (Close into Fault Trip Time Delay) This is intended for single breaker applications (two relays protect different lines, control the same breaker and use the same voltage transformer). The relay with voltage and current transformers on opposite sides of the breaker will be set with the close into fault logic, the other without. The close into fault logic will be blocked for the specified time delay after the common breaker closes to prevent close into fault tripping for fault conditions on the other relay s protected line. STUB BUS TRIP (Stub Bus Trip) Stub bus protection employs the 89b contact from an open disconnect switch in conjunction with medium set overcurrent to high speed trip on overcurrent only, for faults on the stub between the current transformers and the open disconnect switch. This is to compensate for the lack of a potential source connected to the line side of the open disconnect switch. The operation is independent of breaker position(s) and the line voltage condition. TD 51 RI (Time Delayed Reclose Initiate on Overcurrent Trip) There are two outputs for reclose initiate functions. One for high speed reclose initiate and the other for a time delayed reclose initiate. Usually high speed tripping functions...high set overcurrent, Zone-1 and pilot, provide a high speed reclose initiates where synchro-checking is normally not required for reclosing. Time delayed tripping functions...zone-2, Zone-3 and time delayed overcurrent issue a time delayed reclose initiate where synchro-checking is required. Choosing ENABLE allows time delayed reclosing for all faults. By selecting DISABLE, all reclosing is prohibited, except as governed by other elements. Voltage Elements and Logic Functions UV PH PU (Phase Undervoltage Pickup) This unit monitors the phase rms voltages and provides a low voltage alarm output when a phase voltage drops below the set value. The output is also used in the Loss of Potential Block logic. The setting range is 40 to 60 volts in 0.1 volt increments. OV GND PU (Ground Overvoltage Pickup) This unit monitors the phase rms voltages and to provide input to the Loss of Potential Block logic. The setting range is 1 to 120 volts in 0.1 volt increments Settings and Application

93 LOP BLOCK (Loss of Potential Block) This function identifies a loss of phase potential that is the result of a long term (steady state) condition such as a blown phase fuse or an open voltage transformer winding or connection. The setting BLK ALL TRIPS will block all tripping while the relay is in this condition. The setting BLK DIST TRIP will block all tripping by the impedance units. DISABLE will permit tripping for this condition. A LOP alarm is also provided. System Type Logic The following settings define the type of distance protection used. System Type (Pilot/Non-pilot) SYSTEM TYPE (System Type Selection) The relaying logic varies with the selected system type. PILOT SYSTEMS utilize a communications channel in a variety of ways and the proper logic is automatically assigned when the pilot system type is chosen. The communications channel allows information from the remote terminal to be compared with local information. If both terminals agree that there is an internal fault, simultaneous tripping occurs at both transmission line terminals. Step distance allows each terminal to operate completely independently. Faults occurring in Zone 1 cause immediate tripping. For Zone 2 faults, tripping is delayed. Tripping is even further delayed for forward Zone 3 faults. Thus a stair-case plot may be used to describe the tripping speed versus fault location. This leads to the term STEP DISTANCE. Simultaneous occurs at the two transmission line terminals for all faults producing operation of both Zone 1 elements. Sequential tripping occurs for faults near one terminal for which the remote Zone 1 element does not operate. LOAD LOSS TRIP permits tripping to occur for faults producing Zone 2 operation, providing pre-fault load current existed and one or two phase currents drop to zero, indicating loss of load current in the unfaulted phases by the tripping of the remote breaker by remote Zone 1 operation. This concept is unworkable where large tapped loads are fed off of the protected line or when 3-phase faults occur. Zone 1 extension (ZONE 1 EXTEND) logic may be selected to produce high speed tripping for all faults. Using this concept, reliance must be placed on reclosing to restore the line should overtripping occur. Step Distance (Non-pilot) Scheme Selection STEP DISTANCE (Non-pilot Step Distance Scheme) Choosing this option allows access to three non-pilot systems. It is chosen when no reliable communications medium is available for use with relaying. 3 ZONE - This choice provides three zones of distance protection, each of which consists of 3 ground units, a phase-to-phase element and 2 single phase units for 3-phase fault detection. Zones 1 and 2 are for forward protection only, but Zone 3 may be used in a forward or reverse function. The following selections complement the 3 zone protection described above: LOAD LOSS TRIP - The load loss trip scheme is very effective in achieving some of the benefits of pilot relaying without requiring a communications channel. It should be selected where tapped load is nonexistent or small, Zone 2 trip time is unacceptably long and a communications channel is not available. The low set phase pickup, 50L, for this application must be greater than the maximum tapped load on the protected line. Settings and Application 4-29

94 ZONE 1 EXTEND - Zone 1 extension would more appropriately be called Zone 1 contraction. At rest (using a Zone 2 setting) the relay is set to overreach the next bus. It will then detect all faults on the protected line (except those with inordinately high ground resistance) and some into the remote line sections. Following trip, the reach of the Zone 1 element is automatically contracted to the normal Zone 1 reach. Any overtripping which results from this action will be corrected by reclosing, restoring sound lines to service and isolating the faulted line if the fault has not cleared. This scheme should be selected where high speed clearing of remote end zone faults is preferable to the momentary breaker operations (trip and reclose) at the remote bus. Pilot Scheme Selection PILOT SYSTEM (Pilot System Scheme) The best choice of a pilot system is, in large measure, dictated by the nature of the communications channel. If the transmission line itself is part of the communications path, as for power line carrier, loss of the channel is one of the probable results of an internal fault. On the other hand, channels which do not include the protected transmission line as part of the signal path, may be used in a command mode to request or demand tripping upon being received. This would include pilot wires, fiber optics, and microwave. Four systems are offered: POTT Permissive Overreach Transfer Trip PUTT Permissive Underreach Transfer Trip UNBLOCKING Directional Comparison Unblocking BLOCKING Directional Comparison Blocking Any one of the pilot system types may be selected. This assigns the appropriate logic and opens up other refinements of the chosen system for display and selection. Permissive Overreach Transfer Trip (POTT) The permissive overreaching transfer-trip system uses a frequency-shift tone channel on pilot wires or on microwave that is keyed by the pilot phase or ground element. A signal must be transmitted and received from each location to all other for all internal faults. Only one overreaching zone is required at each terminal. Permissive means that a local distance unit must operate, in addition to receiving the remote signal requesting trip, in order for tripping to occur. Overreaching means that the channel is keyed by an element that is set to reach beyond the next bus. POTT 3 TERM LN (POTT Three Terminal Line Logic) For a three terminal line, the logic is selected to require that the channel trip signal be received from two remote terminals. Choosing ENABLE imposes this requirement. Choosing DISABLE commits the logic to two terminal operation and only one channel trip is required. POTT WEAKFEED (POTT Weakfeed Terminal Selection) A weakfeed terminal is one from which inadequate current is supplied to an internal fault to operate any distance or overcurrent element. Faults external to the weak terminal can be identified by the fact that the reverse looking pilot relay operates. This prevents weakfeed [echo] keying. For an internal fault, undervoltage (on any phase) without operation of a reverse pilot element identifies the fault location as internal. This logic is activated by selecting ENABLE. Permissive Underreach Transfer Trip (PUTT) The permissive underreaching transfer trip system uses a frequency shift tone channel on pilot wires or on microwave. A signal must be transmitted from any location to all others for all internal faults. The 4-30 Settings and Application

95 system is called underreaching, because the underreaching phase and ground distance element (Zone 1) keys the channel to cause it to shift from the guard frequency to the trip frequency. Recognition, at the receiving terminal, of this shift plus operation of an overreaching distance element (pilot phase and ground) produces tripping. Zone 1 tripping at the terminal near the fault takes place without regard to the channel. The majority of faults will be detected, using this scheme, by the operation of the Zone 1 relays at both terminals. PUTT 3 TERM LN (PUTT Three Terminal Line Logic) Using the permissive underreaching transfer trip scheme in a 3 terminal application requires considerable care. All faults must be seen by a Zone 1 relay at one of the terminals. All forward pilot zone relays must see all internal faults (phase or ground) with worst-case infeed effects considered. To choose the 3 terminal logic select ENABLE. For two terminal applications select DISABLE. Directional Comparison Unblocking The unblocking system differs from the POTT system in the manner in which loss of channel is treated. In the POTT scheme, the channel trip signal must be received for the tripping logic to be satisfied. In the UNBLOCKING scheme, two modes of tripping are accommodated. If the channel trip signal is received, the system behaves exactly like the POTT scheme. If the fault causes channel failure, a period of 150 ms is allowed in which pilot phase or ground distance element operation causes tripping. Channel failure without pilot distance operation produces the same trip block action as for the POTT scheme. UNBLK 3TERM LN (Unblocking Three Terminal Line Logic) For a three-terminal line, the logic is selected to provide a channel trip when receiving both trip (unblock) signals from the other two locations, when one is received for 150 ms and the other is not, or for a period of 150 ms following loss of signal from both of the remote stations. The forward pilot phase or ground element operating during the 150 ms interval will produce tripping. UNBLK WEAKFEED (Unblocking Weakfeed Terminal Selection) A weakfeed terminal is one from which inadequate current is supplied to an internal fault to operate any distance or overcurrent element. Faults external to the weak terminal can be identified by the fact that the reverse looking pilot relay operates. This breaks up (prevents) echo keying. For an internal fault, undervoltage (on any phase) without operation of a reverse pilot element identifies the fault location as internal. This logic is activated by selecting ENABLE. Directional Comparison Blocking The blocking scheme uses on-off power line carrier to identify to a remote terminal that the local terminal has detected on external fault. Internal faults require no signal transmission or reception. External faults require that some element (DV/DI, Reverse pilot, or low set zero sequence overcurrent) operate the start carrier. CHAN COORD TM (Channel Coordination Timer) The channel coordination timer permits coordination of the REL 500 Series relay with other generation or manufacturer s relays. It delays pilot tripping for a set period of time to insure an opportunity to receive a blocking signal from the remote terminal for faults beyond that terminal. The remote terminal operating time to send a blocking signal (usually to detect and operate for reverse faults) and channel time with 20% margin is recommended. Settings and Application 4-31

96 RCV PULSE STR (Receive Pulse Stretch Time) This setting enhances the security of the blocking system operation. Some power line carrier receiver products are subject to momentary signal losses and do not sustain a continuous receive (blocking) signal to the relay. The tripping logic, once armed, permits tripping instantaneously upon the momentary loss of the blocking signal. The pulse stretching logic allows the relay to ride through the momentary signal losses which are usually not more than 2 to 4 ms. Pilot System Reclosing PS RECL INIT (Pilot System Reclose Initiate) High speed reclosing, to be successful, must occur following high speed simultaneous tripping of the breakers at each end of the transmission line. Pilot tripping may be allowed to initiate high speed reclosing by selecting HIGH SPEED. Time delayed reclosing is usually applied with time delayed tripping, but may be desired depending on the application. Choosing HIGH SPEED or TIME DELAY allows further choices regarding the types of faults for which high speed or time delayed reclosing is desired. By selecting DISABLE, all high speed and time delayed reclosing is prohibited, except as governed by other elements. PS RI FLT TYPE (Pilot System Reclose Initiate Fault Type) To limit reclosing to only those cases involving phase-to-ground faults (for which the impact on nearby generators is limited), select PH-GND. To allow reclosing for both phase-to-ground and phase-tophase faults, select PH-GND/PH-PH. To allow reclosing for all faults for which the pilot system operates, select ALL FAULTS. If time delayed reclosing is selected ALL FAULTS is usually appropriate. PS TD FAULTS (Pilot System Time Delayed Faults) This setting applies to applications where PS RECL INIT is selected as HIGH SPEED and PS RI FAULT TYPE is other than ALL FAULTS. If it is desired to time delay reclose for fault types not selected for high speed relcosing, then this setting should be ENABLE. PS SLOW CLR RB (Pilot System Slow Clearing Reclose Block) Slow clearing is when a permissive signal is received or a blocking signal is stopped 8 cycles after the detection of a forward fault. This condition implies that the remote terminal breaker has not operated and the remote relay is in the breaker failure mode. In the breaker failure mode the remote terminal will send a permissive or stop the blocking signal and block reclosing. To block reclosing at the local terminal for this condition select ENABLE. The DISABLE setting will permit reclosing as defined above. Trip Type TRIP TYPE (System Trip Type) The REL512 may be applied for three pole or single pole tripping. The settings are 3 POLE TRIP and SP TRIP. For 3 POLE TRIP all 3 breaker poles are tripped simultaneously for all faults. For SP TRIP only the faulted phase breaker pole trips for single phase-to-ground faults Settings and Application

97 SP 62TRP TMR (Single Pole Trip 62T Timer) The Single Pole Trip Timer will start when a single pole trip command has been issued and the 50N low set overcurrent function is picked up. The function will issue a three pole trip after the time has elapsed if the 50N low set overcurrent unit it still asserted. The 62T timer should be set longer than the maximum single pole dead time for the recloser but shorter than the Single Pole Open Pole Timer. SP TRIP TMR (Single Pole Open Pole Timer) The Single Pole Open Pole Timer is used to provide a three pole trip for evolving faults occurring after the measuring element has reset following a single pole trip. The timer should be set longer than the maximum single pole dead time for the recloser. SPT RECLOSE INITIATE (Single Pole Trip Reclose Initiate) The settings are SINGLE POLE and 3 POLE. Note that the single pole trip reclose initiate will also follow the settings for PILOT SYSTEM RECLOSE INITIATE. SPT BKR2 OUT (Single Pole Trip breaker #2 Trip Outputs) Thes setting provides three additional trip outputs that may be applied for single or three pole tripping. Settings and Application 4-33

98 Breaker Failure Protection Breaker failure coordination requires the consideration of many timing factors. These include breaker interrupting time, 50 overcurrent dropout time, local backup clearing time and transfer trip and remote backup clearing times. BF SHORT TIMER (Breaker Failure Short Timer) The Breaker Failure Short Timer applies to the clearing of only multi-phase faults. The setting range is 50 to 400 ms in 1 ms increments. It should allow ample margin to allow the breaker to interrupt current and clear. If at the end of the short timer setting the 50 low set overcurrent unit is still asserted, the breaker failure trip output will assert to operate the 86BF lockout function. The 86BF lockout is normally an external function, but may be implemented via the relay s programmable logic. BF LONG TIMER (Breaker Failure Long Timer) The Breaker Failure Long Timer applies to the clearing of all faults and should allow ample margin to allow the breaker to interrupt current and clear. The setting range is 50 to 400 ms in 1 ms increments. If at the end of the long timer setting the 50 low set overcurrent unit is still asserted, The breaker failure trip output will assert to operate the 86BF lockout function. The 86BF lockout is normally an external function, but may be implemented via the relay s programmable logic. BF CONTROL TMR (Breaker Failure Control Timer) The breaker failure control timer is an on-delay timer that resets the breaker failure operation. The setting range is 10 to 500 ms in 1 ms increments. It must be set to a time greater than the BF LONG TIMER plus local 86BF lockout initiation time and transfer trip time to start remote clearing. Protection I/O Mapping Input Map Signals 85CO Pilot is enabled or disabled. This signal is mapped to a voltage input when the relay is applied with a pilot schemeand high speed reclosing. A voltage input enables the selected pilot scheme. No voltage disables the pilot scheme and high speed reclosing and the relay operates as a step-distance scheme without high speed reclosing. 89B CLOSED Line Disconnect Switch 89b contact is closed. This signal is mapped to a voltage input when the relay is applied with stub bus protection. A voltage input indicates that the line disconnect switch is open and enables the stub bus trip logic. BREAKER 1 CLOSED 52A Breaker #1 is closed as indicated by auxiliary contact 52a being closed. This signal is mapped to a voltage input when the breaker status is used. It is also used for trip coil monitoring logic or other programmable logic. BREAKER 1 OPEN 52B Breaker #1 is open as indicated by auxiliary contact 52b being closed. This signal is mapped to a voltage input when the breaker status is used. It is also used for close into fault and pilot logic or other programmable logic Settings and Application

99 BREAKER 2 CLOSED 52A Breaker #2 is closed as indicated by auxiliary contact 52a being closed. This signal is mapped to a voltage input when the breaker status is useded. It is also used for trip coil monitoring logic or other programmable logic. BREAKER 2 OPEN 52B Breaker #2 is open as indicated by auxiliary contact 52b being closed. This signal is mapped to a voltage input when the breaker status is used. It is also used for close into fault and pilot logic or other programmable logic. CHANNEL BLOCK 1 The channel block or guard signal used in two terminal or three terminal unblocking pilot schemes. This signal is mapped to a voltage input that interfaces with the pilot channel equipment. Voltage at the input blocks pilot operation. This signal is required for both two and three terminal applications. CHANNEL BLOCK 2 The second channel block or guard signal used in three terminal unblocking pilot schemes. This signal is mapped to a voltage input that interfaces with the pilot channel equipment. Voltage at the input blocks pilot operation. This signal is required only for three terminal applications. CHANNEL RECEIVE 1 The channel receive or trip permissive signal used in two terminal or three terminal POTT, Unblocking or PUTT pilot schemes. It is also the block trip signal for DCB pilot schemes. This signal is mapped to a voltage input that interfaces with the pilot channel equipment. This signal is required for both two and three terminal applications. CHANNEL RECEIVE 2 The second channel receive or trip permissive signal used in three terminal POTT, Unblocking or PUTT pilot schemes. This signal is mapped to a voltage input that interfaces with the pilot channel equipment. This signal is required for three terminal applications. TRIP COIL 1 MONITOR This signal is mapped to a voltage input that monitors the voltage drop across the trip contacts. TRIP COIL 2MONITOR This signal is mapped to a voltage input that monitors the voltage drop across the trip contacts. 86T This signal is mapped to a voltage input when initiating breaker failure logic from an external source, such as a transformer differential operation, is desired. XLED RESET This signal is mapped to a voltage input when it is desired to reset the front panel LED s from an external source. XBFI This signal is mapped to a voltage input when it is desired to initiate the breaker failure logic from an external source. Settings and Application 4-35

100 XDFR This signal is mapped to a voltage input when it is desired to trigger a digital fault record from an external source. TRIP BLOCK This signal is mapped to a voltage input when it is desired to block all tripping during specific operating conditions, such as bus potential transfer. When this signal is asserted it will block all tripping units and output contacts except for programmable relay outputs 2, 3 and 4. Output Map Signals HS TRIP Highset overcurrent trip (DSP). Z1 TRIP Zone-1 trip (DSP). PFT Forward pilot zone and logic operated (DSP). This signal will operate even if forward pilot tripping is disabled. It also drives the FORWARD PILOT TRIP and time delay logic. PRT Reverse pilot zone and logic operated (DSP). This signal will operate even if reverse pilot tripping is disabled. It also drives the REVERSE PILOT TRIP and time delay logic. 50M SUPV PHASE Any phase current exceeds the 50M SUPV PHASE setting. 50M SUPV 3PH All phase currents exceed the 50M SUPV PHASE setting. UNDERVOLTAGE Any phase voltage is below the phase undervoltage setting UV PH PU. 3PH UNDERVOLTAGE All phase voltages are below the phase undervoltage setting UV PH PU. FORWARD GF Forward ground fault directional unit operated based on the set polarization method. REVERSE GF Reverse ground fault directional unit operated based on the set polarization method. FORWARD 3PH Forward three-phase fault directional unit operated. REVERSE 3PH Reverse three-phase fault directional unit operated Settings and Application

101 59N OVERVOLTAGE Zero sequence (ground) overvoltage exceeds the OV GND PU setting. OSB Starting or in a power swing condition. BREAKER FAILURE TRIP Operates after the set breaker failure time delay. BREAKER FAILURE RETRIP Sends another trip signal to the breaker. INNER BLINDER The impedance measured by the relay is within the inner blinder characteristics. OUTER BLINDER The impedance measured by the relay is within the outer blinder characteristics. LOSS OF CURRENT ALARM Indicates an abnormal loss of current condition. LOSS OF POTENTIAL BLOCK DIST Indicates an abnormal loss of potential condition. It is generally the result of a blown potential transformer fuse. PILOT CHANNEL START Used with pilot scheme applications. Interfaces to external channel equipment to send a permissive (for POTT, PUTT or Unblock) or block (for DCB) signal to remote terminals. PILOT CHANNEL STOP Stops the channel start indicating a forward fault for DCB pilot schemes. ZONE 2 TRIP Indicates when the Zone-2 unit operated and the Zone-2 timer has expired resulting in a trip. ZONE 3 TRIP Indicates when the Zone-3 unit operated and the Zone-3 timer has expired resulting in a trip. RECLOSE BLOCK Reclose block signal to interface with external reclosing devices. BKR FAIL RB Reclose block signal indicated as a result of a slow operating breaker to interface with an external reclosing device. HSRI A reclose initiate signal produced by high-speed tripping. TDRI A reclose initiate signal produced by time-delay tripping. Settings and Application 4-37

102 BREAKER FAILURE INITIATE Breaker failure initiate signal to interface with external breaker failure devices. TCM/52 ALARM 1 Trip coil failure alarm #1. TCM/52 ALARM2 Trip coil failure alarm #2. Notes 4-38 Settings and Application

103 Settings Tables Guide to Settings Tables The settings tables are provided as a quick reference to the relay setting information. Shown in the tables are the setting name, the relay operating element or logic name the setting controls, the default setting, setting range and increment, and the setting units. The settings may either be a range of values with incremental steps (Min Max [INCR]) or a list of choices (Choice #1, #2, etc.). The tables are divided into groups based on application. Relay Configuration SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Relay Location and Identification STATION NAME Substation Name Station Name 14 Characters BAY NAME Bay Name Bay Name 14 Characters LINE NAME Line Name Line Name 14 Characters Power System Parameters GND DIR POL Ground Directional Polarization 3V0 3V0, 3V2, 3V0/IP ---- EXT SET SELECT External Setting Selector DISABLE ENABLE, DISABLE Settings and Application 4-39

104 Relay Configuration (continued) SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Front RS-232 Configuration Port Settings FRNT BIT RATE Front Communication Port Bit Rate , 9600, 19200, BPS FRNT DATA LGTH Front Communication Port Word Length 8 7, 8 FRNT PARITY Front Communication Port Parity NONE NONE, ODD, EVEN FRNT STOP BITS Front Communication Port Stop Bits 2 1, 2 Rear RS-232 Configuration Port Settings REAR BIT RATE Rear Communication Port Bit Rate , 9600, 19200, BPS REAR DATA LGTH Rear Communication Port Word Length 8 7, 8 REAR PARITY Rear Communication Port Parity NONE NONE, ODD, EVEN REAR STOP BITS Rear Communication Port Stop Bits 2 1, 2 Modbus + Network Port Settings DNP 3.0 Network Port Settings See Modbus+ Support Document See DNP 3.0 Support Document Data Display and Recording VT RATIO Voltage Transformer Turns Ratio ,000 [1] CT RATIO Current Transformer Turns Ratio [1] UNITS PRI/SEC Data Display and Target Metering Base SECONDARY PRIMARY, SECONDARY ---- DATA CAPTURE Other Set Date and Time Data Capture Triggering Operation Set the date and time via ASCII Interface. PILOT PILOT, TRIP, DVDI ---- Active Group Sets the active group when asettings file is downloaded to the relay Settings and Application

105 Protection Settings SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Zone-1 Z1 K0 MAG Z1 K0 ANG Zone-1 Zero Sequence Compensation Magnitude Zone-1 Zero Sequence Compensation Angle [0.01] [1] DEG Z1 LINE ANG Zone-1 Line Angle [1] DEG Z1 PH REACH Zone-1 Phase Reach * [0.01] [0.05]* OHMS Z1 PH TRIP Zone-1 Phase Trip ENABLE ENABLE, DISABLE ---- Z1 GND REACH Zone-1 Ground Reach * [0.01] [0.05]* OHMS Z1 GND TRIP Zone-1 Ground Trip ENABLE ENABLE, DISABLE ---- Z1 GND BULLET Zone-1 Ground Bullet DISABLE ENABLE, DISABLE ---- Z1 RESISTANCE Zone-1 Ground Resistance * [0.01] [0.05]* OHMS Z1 OS BLOCK Zone-1 Out-of-Step Block DISABLE ENABLE, DISABLE ---- Z1 RECL INIT Zone-1 Reclose Initiate HIGH SPEED HIGH SPEED, TIME DELAY, DISABLE ---- Z1 RI FLT TYPE Zone-1 Reclose Initiate Fault Type ALL FAULTS PH-GND, PH-GND/ PH-PH, ALL FAULTS ---- Z1 TD FAULTS Zone-1Time Delayed Faults DISABLE ENABLE, DISABLE ---- *1 A CT input Settings and Application 4-41

106 SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Zone-2 Z2 K0 MAG Z2 K0 ANG Zone-2 Zero Sequence Compensation Magnitude Zone-2 Zero Sequence Compensation Angle [0.01] [1] DEG Z2 LINE ANG Zone-2 Line Angle [1] DEG Z2 PH REACH Zone-2 Phase Reach * [0.01] [0.05]* OHMS Z2 PH DLY Zone-2 Phase Time Delay [0.01] SEC Z2 PH TRIP Zone-2 Phase Trip ENABLE ENABLE, DISABLE ---- Z2 GND REACH Zone-2 Ground Reach * [0.01] [0.05]* OHMS Z2 GND DLY Zone-2 Ground Time Delay [0.01] SEC Z2 GND TRIP Zone-2 Ground Trip ENABLE ENABLE, DISABLE ---- Z2 OS BLOCK Zone-2 Out-of-Step Block DISABLE ENABLE, DISABLE ---- Z2 RECL INIT Zone-3 Z3 K0 MAG Z3 K0 ANG Zone-2 Time Delayed Reclose Initiate on All Faults Zone-3 Zero Sequence Compensation Magnitude Zone-3 Zero Sequence Compensation Angle DISABLE ENABLE, DISABLE [0.01] [1] DEG Z3 LINE ANG Zone-3 Line Angle [1] DEG Z3 PH REACH Zone-3 Phase Reach * [0.01] [0.05]* OHMS Z3 PH DLY Zone-3 Phase Time Delay [0.01] SEC Z3 PH TRIP Zone-3 Phase Trip ENABLE ENABLE, DISABLE ---- Z3 GND REACH Zone-3 Ground Reach * [0.01] [0.05]* OHMS Z3 GND DLY Zone-3 Ground Time Delay [0.01] SEC Z3 GND TRIP Zone-3 Ground Trip ENABLE ENABLE, DISABLE ---- Z3 OS BLOCK Zone-3 Out-of-Step Block DISABLE ENABLE, DISABLE ---- Z3 RECL INIT *1 A. CT input Zone-3 Time Delayed Reclose Initiate on All Faults DISABLE ENABLE, DISABLE Settings and Application

107 SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Forward Pilot FWP K0 MAG FWP K0 ANG Forward Pilot Zero Sequence Compensation Magnitude Forward Pilot Zero Sequence Compensation Angle [0.01] [1] DEG FWP LINE ANG Forward Pilot Line Angle [1] DEG FWP PH REACH Forward Pilot Phase Reach * [0.01] [0.05]* OHMS FWP PH DLY Forward Pilot Phase Time Delay [0.01] SEC FWP PH TRIP Forward Pilot Phase Trip ENABLE ENABLE, DISABLE ---- FWP GND REACH Forward Pilot Ground Reach * [0.01] [0.05]* OHMS FWP GND DLY Forward Pilot Ground Time Delay [0.01] SEC FWP GND TRIP Forward Pilot Ground Trip DISABLE ENABLE, DISABLE ---- FWP OS BLOCK Reverse Pilot RVP K0 MAG RVP K0 ANG Forward Pilot Out-of-Step Block Reverse Pilot Zero Sequence Compensation Magnitude Reverse Pilot Zero Sequence Compensation Angle DISABLE ENABLE, DISABLE [0.01] [1] DEG RVP LINE ANG Reverse Pilot Line Angle [1] DEG RVP PH REACH Reverse Pilot Phase Reach * [0.01] [0.05]* OHMS RVP PH DLY Reverse Pilot Phase Time Delay [0.01] SEC RVP PH TRIP Reverse Pilot Phase Trip DISABLE ENABLE, DISABLE ---- RVP GND REACH Reverse Pilot Ground Reach * [0.01] [0.05]* OHMS RVP GND DLY Reverse Pilot Ground Time Delay [0.01] SEC RVP GND TRIP Reverse Pilot Ground Trip DISABLE ENABLE, DISABLE ---- *1 A. CT input Settings and Application 4-43

108 SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Line Characteristics LN LGTH UNITS Line Length Units for Data Display MILES KILOMETERS* MILES, KILOMETERS ---- LN R PU LN X PU Resistance of Line per Unit Length (ohms/unit secondary) Reactance of Line per Unit Length (ohms/unit secondary) [0.0001] OHMS [0.0001] OHMS Out-of Step and Load Restriction LD RESTRICTON Load Restriction Enable or Disable DISABLE ENABLE, DISABLE ---- OS TYPE Out-of-Step Logic for Block Tripping of Tripping DISABLE OS BLOCK, OS TRIP, DISABLE ---- Out-of-Step Trip OST TIME 1 Out of Step Trip Time [0.01] SEC OST TIME 2 Out of Step Trip OST Time [0.01] SEC OST RESET TIME Out of Step Dropout Time [0.01] SEC OST WAY IN OUT Out of Step Trip OST Way In Out WAY OUT WAY IN, WAY OUT ---- Out-of-Step Block/Trip OS OVRD TM Blinders Out of Step Block Override Time [0.01] SEC BLINDER ANG Blinder Angle [1] DEG BLNDR INNER R Inner Blinder Resistive Reach * [0.01] [0.05]* OHMS BLNDR OUTER R Outer Blinder Resistive Reach * [0.01] [0.05]* OHMS *1 A. CT input 4-44 Settings and Application

109 SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS High Set Overcurrent Elements and Functions HS 50P PU High Set Phase Pickup 30 6* [0.1] [0.02}* AMP HS 50N PU High Set Ground Pickup 30 6* [0.1] [0.02}* AMP HS 50Q PU High Set Negative Sequence Pickup 10 2* [0.1] [0.02}*] AMP HS 50P TRIP High Set Phase Trip DISABLE ENABLE, DISABLE ---- HS 50P DIR High Set Phase Directional DISABLE ENABLE, DISABLE ---- HS 50N TRP High Set Ground Trip DISABLE ENABLE, DISABLE ---- HS 50N DIR High Set Ground Directional DISABLE ENABLE, DISABLE ---- HS 50Q TRP HS 50Q DIR High Set Negative Sequence Trip High Set Negative Sequence Directional DISABLE ENABLE, DISABLE ---- DISABLE ENABLE, DISABLE ---- HS 50 RI High Set Reclose Initiate DISABLE HIGH SPEED, TIME DELAY, DISABLE ---- HS RI FLT TYPE High Set Reclose Initiate Fault Type ALL FAULTS PH-GND, PH-GND PH- PH, ALL FAULTS ---- HS TD FAULTS High Set Time Delayed Faults DISABLE ENABLE, DISABLE ---- Medium Set Overcurrent Elements and Functions MS 50P PU Medium Set Phase Pickup * [0.05] [0.02]* AMP MS 50N PU Medium Set Ground Pickup * [0.1] [0.02]* AMP MS 50Q PU Medium Set Negative Sequence Pickup * [0.1] [0.02]* AMP MS 50N TRP Medium Set Ground Trip DISABLE ENABLE, DISABLE ---- MS 50N DLY Medium Set Ground Time Delay [0.01] SEC MS 50Q TRP MS 50Q DLY Medium Set Negative Sequence Trip Medium Sequence OC Time Delay DISABLE ENABLE, DISABLE [0.01] SEC Low Set Overcurrent Elements and Functions LS 50P PU Low Set Phase Pickup * [0.1] [0.02]* AMP LS 50N PU Low Set Ground Pickup * [0.1] [0.02]* AMP *1 A. CT input Settings and Application 4-45

110 SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Phase Time Overcurrent Elements TD 51P 51 Phase Time Overcurrent Backup DISABLE ENABLE, DISABLE ---- TD 51P PU 51 Phase Time Overcurrent Bacup Pickup * [0.05] [0.01]* AMP TD 51P A VALUE TD 51P B VALUE TD 51P P VALUE TD 51P TR VAL TD 51P TM DIAL 51 Phase Time Overcurrent A Value 51 Phase Time Overcurrent B Value 51 Phase Time Overcurrent P Value 51 Phase Time Overcurrent Tr Value 51 Phase Time Overcurrent Backup Time Dial [0.001] SEC [0.001] SEC [0.01] [0.01] SEC [0.1] ---- TD 51P CONTROL 51 Phase Time Overcurrent Backup Torque Control DIR FORWARD DIR FORWARD, DIR REVERSE, Z2 CONTROL, NONE ---- Negative Sequence Time Overcurrent Elements TD 51Q 51 Negative Sequence Time Overcurrent Backup DISABLE ENABLE, DISABLE ---- TD 51Q PU 51 Negative Sequence Time Overcurrent Backup Pickup * [0.05] [0.01]* AMP TD 51Q A VALUE TD 51Q B VALUE TD 51Q P VALUE TD 51Q TR VAL TD 51Q TM DIAL 51 Negative Sequence Time Overcurrent A Value 51 Negative Sequence Time Overcurrent B Value 51 Negative Sequence Time Overcurrent P Value 51 Negative Sequence Time Overcurrent Tr Value 51 Negative Sequence Time Overcurrent Backup Time Dial [0.001] SEC [0.001] SEC [0.01] [0.01] SEC [0.1] ---- TD 51Q CONTROL 51 Negative Sequence Time Overcurrent Torque Control DIR FORWARD DIR FORWARD, DIR REVERSE, Z2 CONTROL, NONE ---- *1 A. CT input 4-46 Settings and Application

111 SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Ground Time Overcurrent Elements TD 51N 51 Ground Time Overcurrent Backup DISABLE ENABLE, DISABLE ---- TD 51N PU 51 Ground Time Overcurrent Bacup Pickup * [0.05] [0.01]* AMP TD 51N A VALUE TD 51N B VALUE TD 51N P VALUE TD 51N TR VAL TD 51N TM DIAL 51 Ground Time Overcurrent A Value 51 Ground Time Overcurrent B Value 51 Ground Time Overcurrent P Value 51 Ground Time Overcurrent Tr Value 51 Ground Time Overcurrent Backup Time Dial [0.001] SEC [0.001] SEC [0.01] [0.01] SEC [0.1] ---- TD 51N CONTROL 51 Ground Time Overcurrent Backup Torque Control DIR FORWARD DIR FORWARD, DIR REVERSE, Z2 CONTROL, NONE ---- Other Overcurrent Element and Logic Functions CIFT Close Into Fault Trip DISABLE ENABLE, DISABLE ---- CIFT TM DLY Close Into Fault Trip Time Delay DISABLE ENABLE, DISABLE ---- STUB BUS TRIP Stub Bus Trip DISABLE ENABLE, DISABLE ---- TD 51 RI Overcurrent Trip Time Delay Reclose Init on All Faults DISABLE ENABLE, DISABLE ---- Voltage Elements and Logic Functions UV PH PU Phase Undervoltage Pickup [0.1] VOLT OV GND PU Ground (3V 0 ) Overvoltage Pickup [0.1] VOLT LOP BLOCK Loss of Potential Block DISABLE *1 A. CT input BLK DIST TRIP, BLK ALL TRIPS, DISABLE ---- Settings and Application 4-47

112 SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS System Type Selection SYSTEM TYPE System Type Selection STEP DISTANCE Step Distance Scheme Selection STEP DISTANCE, PILOT SYSTEM ---- STEP DISTANCE Step Distance Scheme Selection 3 ZONE 3 ZONE, LOAD LOSS TRIP ZONE 1 EXTEND ---- Pilot Scheme Selection PILOT SCHEME Pilot System Scheme Selection POTT Permissive Overreaching Transfer Trip POTT, PUTT, BLOCKING, UNBLOCKING ---- POTT 3 TERM LN POTT WEAKFEED POTT 3 Terminal Line Protection POTT Weakfeed Terminal Protection DISABLE ENABLE, DISABLE ---- DISABLE ENABLE, DISABLE ---- Permissive Underreaching Transfer Trip PUTT 3 TERM LN PUTT 3 Terminal Line Protection DISABLE ENABLE, DISABLE ---- Directional Comparison Unblocking UNBLK 3 TERM LN UNBLK WEAKFEED Unblocking 3 Terminal Line Protection Unblocking Weakfeed Terminal Protection DISABLE ENABLE, DISABLE SEC DISABLE ENABLE, DISABLE SEC Directional Comparison Blocking CHAN COORD TM Channel Coordination Timer [0.001] SEC RCV PULSE STR Receive Pulse Stretch Timer [0.001] SEC Pilot Reclosing Functions PS RECL INIT Pilot System Reclose Initiate DISABLE HIGH SPEED, TIME DELAY, DISABLE ---- PS RI FLT TYPE Pilot System Reclose Initiate Fault Type ALL FAULTS PH-GND, PH-GND PH- PH, ALL FAULTS ---- PS TD FAULTS PS SLOW CLR RB Pilot System Time Delayed Faults Slow Pilot Clearing Relcose Block DISABLE ENABLE, DISABLE ---- DISABLE ENABLE, DISABLE Settings and Application

113 SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Trip Type Selection TRIP TYPE Trip Type Selection 3 POLE TRIP Single Pole Trip 3 POLE TRIP SP TRIP ---- SP 62T TRIP TMR Single Pole Trip 62T Timer [0.01] SEC SP TRP TMR Single Pole Trip Open Pole Timer [0.1] SEC SP RECL INIT Single Pole Trip Reclose Initiate SINGLE POLE SINGLE POLE, 3 POLE ---- SPT BKR2 OUT Three Extra Trip Outputs DISABLE ENABLE, DISABLE ---- Breaker Failure Protection BF PROTECTION Breaker Failure Protection DISABLE ENABLE, DISABLE ---- BF SHORT TIMER BF LONG TIMER BF CONTROL TMR Breaker Failure Protection Short Timer Breaker Failure Protection Long Timer Breaker Failure Protection Control Timer [0.001] SEC [0.001] SEC [0.001] SEC Settings and Application 4-49

114 Measuring Elements and Operational Logic Variable Mho Impedance Characteristics There are a total of 30 mho type impedance measuring units, 6 per zone and 5 zones of protection. The Mho Circle The impedance unit operating characteristic is a mho circle. This is shown in Figure 5-1. This is a plot of test results of the three phase unit set to 4 ohms at 75. Given the nature of the inverse characteristic, operation at the boundary cannot be theoretically achieved as the operating time approaches infinity. Figure 5-1. Mho Characteristic Test The test points shown in Figure 5-1 are based on an applied balanced three phase voltage of 40 V and increasing a balanced three phase current for different angles in small increments until operation. This is to provide operation as close to the boundary as possible. The current magnitude is increased in steps from a value that puts the impedance outside the unit s reach. The impedance will decrease with each step until the unit operates. The test points are compared to the theoretical circle shown as a solid line. All impedance units, three phase, phase-to-phase and phase-to-ground for all zones were individually tested over their range of settings to confirm their operating characteristics. Additional testing was performed on the Model Power System to evaluate each units performance to a large number of internal and external (forward and reverse) faults. The test proved quite convincingly the mho characteristic s inherent security to external faults. Measuring Elements and Operational Logic 5-1

115 Memory Voltage Polarization The three-phase impedance measuring units are basic cross- or quadrature-polarized phase-to-ground (neutral) mho units with no zero sequence compensation, but with consideration given to memory voltage polarization. Memory voltage is required to maintain correct polarization in the event of a [near] zero voltage three-phase fault. There are two three-phase units, one for phase A and one for phase B. The phase A unit measures I A Z R - V A and is polarized by V BC. If V BC is very near zero (too small to accurately measure phase angle) then reliable polarization does not occur. Therefore, memory of V BC and V CA is required to correctly polarize the three-phase units on phases A and B. Figure 5-2 Memory Circuit and Response Mimic Circuit The three-phase unit algorithm emulates an electromechanical cylinder unit providing high-speed operation. Therefore, a mimic circuit, which emulates a resonant circuit tuned to the fundamental operating frequency of the relay, is used to provide memory voltage. The polarizing voltage will change from the prefault to fault voltage as affected by the response of mimic circuit. If the fault voltage is zero, the oscillation or ringing of the circuit at the resonant frequency will provide two to three cycles of memory voltage for correct polarization. This is demonstrated in Figure 1. Three-phase Unit Torque Two cycles of memory voltage is more than sufficient for correct operation of the three-phase units. Zero voltage faults are indicative of severe or bolted faults at the relay and will result in large operating or restraining torque. For the REL 512 this will result in a correct operating decision in much less than one cycle. Additionally, once the operating or restraining torque is applied, the operating element will stay biased in that direction for 8 or more cycles depending on the initial applied torque level, or until an opposing torque is applied. Operating Times Operating times based on the source to relay impedance ratio (SIR) are shown in Figure 5-3. SIR is the ratio of the equivalent system source impedance to the relay setting expressed on the same voltage base. The operating times include the mechanical output relay operating time and were determined using a conventional computer controlled test. Model Power System results are approximately 2 ms. faster as the units respond better to real system dynamics. All impedance units have very similar operating characteristics. Optional solid state FET outputs improve the operating time approximately 4-6 ms. Ground-Quadrilateral Characteristics Zone-1 is provided with a complementary set of ground-quadrilateral characteristics and, if enabled, will provide additional coverage for Zone-1 high resistance ground faults. The characteristics are defined by the Zone-1 Reach (Z1 GND REACH), line impedance angle (Z1 LINE ANGLE) and ground fault resistance reach (Z1 RESISTANCE) settings. 5-2 Measuring Elements and Operational Logic

116 Figure 5-4 shows the composite mho-quadrilateral characteristic. The Zone-1 ground impedance reach is set to 4.0 ohms at 75 and the resistance reach is set to 8 ohms. The mho circle and the quad reactive reach (top line of the quad) are zero sequence compensated while the resistance reach (the right line of the quad) is not. This is done to make the quad more secure during load conditions where zero sequence current during a fault may affect the healthy phases. Therefore, the apparent impedance calculated (by test set and other macros) with the compensation factor will be the setting divided by (1 + K0/3) where K0 is the zero sequence compensation factor. In this case the resistance setting is 10 and the K0 setting is 2. Thus, the apparent resistance is 8/(1 + 2/3) or 4.8 ohms. In addition the quad reactive reach is fixed at 85% of the set zone-1 ground reach. The quadrilateral operating time is typically 60 ms. Figure 5-3. Operating Time for SIR of 1 to 20 Figure 5-4 Mho-Quadrilateral Composite Characteristic Measuring Elements and Operational Logic 5-3

117 Blinders The inner and outer blinders are used for out-of-step block and trip functions. The inner blinders are also used for protection against tripping for load conditions that encroach three-phase impedance zones. The blinder characteristic is stated to be parallel lines at a set angle and are used to supervise the three phase mho elements on phases A and B. The blinder characteristic, however, is really lenticular in nature providing essentially the parallel effect within the mho characteristic, but eventually intersecting outside the mho characteristic. Figure 5-5 illustrates the lenticular characteristic. Figure 5-5. Blinder Lenticular Characteristic The blinders are essentially parallel within the range of the mho characteristic. This is illustrated in Figure 5-6 where a 4 ohm mho characteristic is supervised by a 1.5 ohm blinder characteristic. Figure 5-6. A Mho Characteristic Supervised by the Blinder Characteristic 5-4 Measuring Elements and Operational Logic

118 Directional Units Phase Directional Units There are three 3-phase quadrature polarized directional units, one for each phase. The respective phase current is compared to the opposite phase-to-phase voltage. That is, phase I A is referenced to V BC to determine directionality. This is shown in Figure 5-7. The current is shown at the maximum torque angle. Ground Directional Units Figure 5-7 Three Phase Directional Units There are four ground directional units, two forward and two reverse. These are zero sequence voltage polarizing units and zero sequence current polarizing (taken from a transformer) units. The voltage unit compares the V 0 and I 0 as shown in Figure 5-8(a). The transformer current unit compares I P and I 0 as shown in Figure 5-8(b). The current is shown at the maximum torque angle. Figure 5-8. (a) Zero Sequence Voltage Polarization (b) Transformer Zero Sequence Current Polarization Measuring Elements and Operational Logic 5-5

119 Negative Sequence Units There are two negative sequence voltage polarization units, forward and reverse. The negative sequence voltage unit compares the V 2 and I 2 as shown in Figure 5-9. Figure 5-9. Negative Sequence Directional Unit Directional Unit Sensitivity The sensitivity and speed of the directional units depends on the fault energy (torque) seen by the relay. Figure 5-9(a) shows the tested results of the forward ground directional unit sensitivity. This illustrates how the operating bandwidth in degrees around the maximum torque angle decreases with reducing fault energy expressed in volt-amperes (in this case 3V 0 x 3I 0 ). Figure 5-9(b) shows the forward and reverse operating regions for 2.5 VA of fault energy. Normal operations occur in the quadrant around the maximum torque angle. This feature provides additional security against incorrect directional sensing for remote low energy faults influenced by unbalanced phase voltages at the relay. These are typical and will vary slightly depending on the fault voltage and current values. It should also be noted that the corresponding forward and reverse units are very close in their tested characteristics. The zero sequence voltage directional unit minimum sensitivity was found to be approximately 0.83 VA (3V 0 x 3I 0 ) at 3I 0 = 0.25 A and 0.6 VA at 3V 0 = 1.0 V. Refer to Table 1-8 for the measured minimum sensitivity for each of the directional units. Figure Sensitivity of Ground Directional Unit 5-6 Measuring Elements and Operational Logic

120 Operation of the units can be determined using the equation T = VIcos (f) where f is the angle between the maximum torque angle and applied current angle and T is the torque to be compared to the minimum sensitivity defined above. Overcurrent Units Operating Units (Type 50) There are 15 instantaneous overcurrent measuring units. Three high set phase, one zero sequence (ground) and one negative sequence units. All the high set units can be directionally supervised. Three medium set phase, one zero sequence (ground) and one negative sequence units. Three low set phase, one zero sequence (ground) and one negative sequence units. The negative sequence unit has a fixed setting of 0.5 A. Operating Characteristics The operating characteristics for all the instantaneous overcurrent units are approximately the same. These characteristics as determined by test are shown in Figure The units operated very close to the set pickup value and had a pickup/dropout ratio of approximately one. Figure Typical Operating Characteristics for Instantaneous Overcurrent Units Inverse Time Overcurrent TD 51 Inverse Units There are 5 inverse overcurrent units: three phase, one zero sequence (ground) and one negative sequence units. The principle of operation is based on IEEE Standard C37.112, which is discussed in Section 4. The units are CPU measuring units and operate in a backup mode. Timing accuracy is within 5% except at the extreme end ends. Generally accuracy can be improved by subtracting.02 to 0.04 from the B Value setting. The inverse time overcurrent curves for CO-8 family emulation with the appropriate settings constants is shown in Figure 5-12 These curves were computed using the constants and the equation found in Section 4, Settings and Application. The constants for all CO relays are found there. Measuring Elements and Operational Logic 5-7

121 Voltage Units Figure CO-8 Emulation Phase Undervoltage Units There are three undervoltage-measuring units. Undervoltage unit pickup values were tested with less than 0.5% error and a pickup/dropout ratio of (pickup is lower than dropout). Figure 5-12 shows the time to pickup after instant voltage drops to a voltage expressed as percent of the pickup setting. 5-8 Measuring Elements and Operational Logic

122 Figure Operating Characteristics of the Phase Undervoltage Units Ground Overvoltage Unit There is one ground overvoltage measuring unit. The ground (3V 0 ) overvoltage unit pickup values were tested with less than 1.0% error and a pickup/dropout ratio of Figure 5-13 shows the time to pickup after instant voltage increase expressed in multiples of the pickup setting. Figure Operating Characteristics of the Ground Overvoltage Unit Phase Overvoltage Units There are two definite-time phase overvoltage measuring units per phase. One has a fixed time delay of 100 ms. and the second has a settable timer of 0.1 to 10.0 seconds. The time resolution for these units is +/- 50 ms. Measuring Elements and Operational Logic 5-9

123 Measuring Unit to Logic Tables The following tables show all the REL 512 measuring units and identified the DSP and CPU logic modules where they are connected. DSP Measuring Unit DSP Module CPU Module Zone-1 Phase Zone-1 Ground A Zone-1 Ground B Zone-1 Ground C Zone-1 3 Phase A Zone-1 3 Phase B/C Forward Pilot Phase Forward Pilot Ground A Forward Pilot Ground B Forward Pilot Ground C Forward Pilot 3 Phase A Forward Pilot 3 Phase B/C Reverse Pilot Phase Reverse Pilot Ground A Reverse Pilot Ground B Reverse Pilot Ground C Reverse Pilot 3 Phase A Reverse Pilot 3 Phase B/C Zone-2 Phase - Zone-2 Ground A - Zone-2 Ground B Zone-2 Ground C Zone-2 3 Phase A Zone-2 3 Phase B/C Measuring Elements and Operational Logic

124 DSP Measuring Unit DSP Module CPU Module Zone-3 Phase Zone-3 Ground A Zone-3 Ground B Zone-3 Ground C Zone-3 3 Phase A Zone-3 3 Phase B/C - - Phase Selection Zone Ground A Phase Selection Zone Ground B Phase Selection Zone Ground C In Blinder Right A Out Blinder Right A In Blinder Right B Out Blinder Right B In Blinder Left A Out Blinder Left A In Blinder Left B Out Blinder Left B Highset A Highset B Highset C N Highset Q Highset M Supv A M Supv B M Supv C NM Supv QM Supv Measuring Elements and Operational Logic 5-11

125 DSP Measuring Unit DSP Module CPU Module 50L Supv A 50L Supv B 50L Supv C 500, 800, 1000, 2000, 3000, , 800, 1000, 2000, 3000, , 800, 1000, 2000, 3000, NL Supv 300, 500, QL Supv 300, 500, POL Forward Phase A 600, Forward Phase B 600, Forward Phase C 600, Forward 3V Forward 3V2 700, Forward IP Reverse Phase A Reverse Phase B Reverse Phase C Reverse 3V Reverse 3V Reverse IP A Undervoltage A B Undervoltage B C Undervoltage C N Overvoltage 200, Measuring Elements and Operational Logic

126 DSP Measuring Unit DSP Module CPU Module Diff Va Diff Vb Diff Vc Diff 3V Diff Ia Diff Ib Diff Ic Diff 3I CPU Measuring Unit DSP Module CPU Module Backup 51A Backup 51B Backup 51C Backup 51N Backup 51Q Quad Z1 A Quad Z1 B Quad Z1 C Overvoltage A Overvoltage B Overvoltage C Overvoltage A Overvoltage B Overvoltage C Measuring Elements and Operational Logic 5-13

127 Operational Logic There are two logic processors, the digital signal processor (DSP) and the central processing unit (CPU). The DSP computes the measuring units and the high speed logic every relay sample at 20 samples per cycle. The CPU computes a number of logic functions that include pilot, time-delayed tripping and a number of other logic functions. High Speed DSP Logic Figure Logic Legend The following DSP Logic modules are executed in order of the figure number. Inputs to each module are defined on the left of the logic drawing and output logic signals are on the right. The inputs consist of measuring units, binary (contact) inputs, settings and logic signals that were developed in (output from) a previous module. An output logic signal either operates an output contact, used as input to a subsequent DSP or CPU logic module, or made available for programmable output Measuring Elements and Operational Logic

128 Measuring Elements and Operational Logic 5-15

129 5-16 Measuring Elements and Operational Logic

130 Measuring Elements and Operational Logic 5-17

131 5-18 Measuring Elements and Operational Logic

132 Measuring Elements and Operational Logic 5-19

133 5-20 Measuring Elements and Operational Logic

134 Measuring Elements and Operational Logic 5-21

135 5-22 Measuring Elements and Operational Logic

136 CPU Logic CPU logic is executed using input from the DSP logic modules. Logic module execution frequency ranges from 1/4 cycle to 5/4 cycles based on the operating time requirements of the logic function. For example, pilot logic is executed every ¼ cycle while Zone-2 trip time is counted (checked) every 5/ 4 cycles. Measuring Elements and Operational Logic 5-23

137 5-24 Measuring Elements and Operational Logic

138 Measuring Elements and Operational Logic 5-25

139 5-26 Measuring Elements and Operational Logic

140 Measuring Elements and Operational Logic 5-27

141 5-28 Measuring Elements and Operational Logic

142 Measuring Elements and Operational Logic 5-29

143 5-30 Measuring Elements and Operational Logic

144 Measuring Elements and Operational Logic 5-31

145 5-32 Measuring Elements and Operational Logic

146 Measuring Elements and Operational Logic 5-33

147 5-34 Measuring Elements and Operational Logic

148 Measuring Elements and Operational Logic 5-35

149 5-36 Measuring Elements and Operational Logic

150 Measuring Elements and Operational Logic 5-37

151 5-38 Measuring Elements and Operational Logic

152 Notes Measuring Elements and Operational Logic 5-39

153 Notes 5-40 Measuring Elements and Operational Logic

154 RELTOOLs ABB REL 512 Line Protection and Breaker Control Terminal RELTOOLs is a group of programs that supports the REL 512 product and the productivity of the user. The group consists of a settings editor and an application advisor, a programmable logic editor, and a digital fault record analyzer. RELWISE-Settings Editor and Advisor Introduction The Settings Editor and Advisor program, RELWISE, is a REL 512 settings editor providing the means to create, store, view, comment on, print, and edit setting files off line. Additionally, the program provides settings advice through a text window and on line access to the Help, Settings Manual Menu. Once the setting file is created or edited, it can then be uploaded to the relay via your communications program (HyperTerminalä, Crosstalkä, ProCommä etc.). Instructions There are four types of settings that can be edited. These are configuration, protection logic, binary inputs and relay outputs. Setting type selection for editing is made by selecting the appropriate options in the Group and Group View frames. The settings or logic signals are viewed in the Group Parameters text box, and the setting definition for the highlighted setting is viewed in the Help Information text box. Editor Advisor Start Screen File Menu The file menu allows you to create a new settings file, open an existing file, update an older version file, save a file, or print a file. A relay settings file can be down loaded from the relay via the Retrieve Data selection of the relay s main menu. It can be opened in the editor and modified for other applications, and saved under a new name. The correct file extension for setting files is bin (filename.bin). Editor-Advisor This menu allows you to recall the Editor-Advisor window after it is closed to access functions in this and the Help menus.. This menu also provides for opening a second file that can be compared with the primary file to identify different setting values. Editor Advisor File Screen View Configuration This menu allows you to view the relay hardware configuration based on the relay s catalog number. Catalog Number The relay s catalog number is in the V2.3 settings database. The catalog number in the V2.3 relay and in the settings database must match for the relay to accept the settings. The catalog number will automatically block settings in RELWISE that are not used. This menu allows you to set the relay s catalog number. Note : You must have the relay s correct catalog number to upgrade a previous settings database to V2.3. Support Software 7-1

155 Select settings group to edit Settings Copy settings group Settings range and set values Help Information Comments Group Settings There are eight settings groups. Each group has protection logic, input and output settings. The group being edited must be selected Group frame on the left. Group 0 is the configuration settings as it is common to the eight protection settings groups. The protection settings groups can be copied from one group to another using the Copy Group function on the right. Edit Configuration Settings Configuration settings are settings that define the relay location, instrument transformer ratios, data capturing, communications, and etc. that are common for all group settings. Open a file, and to edit a configuration setting, select the system option button in the Group frame and the Logic option in the Group View frame. In the Group Parameters text box select the setting to be edited. The setting range, precision or values are displayed in the Value Limits frame. A new value may be entered into the Value input field. The value will be automatically checked for proper range and precision. If the value is a text entry, a drop down menu will appear in the Value frame to provide for correct selection. Edit Protection Logic Settings Protection logic settings set the threshold values of the relays operating elements, and enable specific blocks of relay system logic. To edit a protection logic setting, select the desired Group option button in the Group frame and the Logic option in the Group View Frame. There are 8 groups to choose from. In the Group Parameters text box. Select the setting to be edited. The setting range, precision or values, are displayed in the Value Limits frame. A new value may be entered into the Value input field. The value will be automatically checked for proper range and 7-2 Support Software

156 precision. If the value is a text entry, a drop down menu will appear in the Value frame to provide for correct selection. It is recommended to set all 8 setting groups. After editing the first group the Copy Group function can be used to copy the edited group to all other groups and then edit as required. This should be done after setting all logic, and inputs and outputs for the first group. Edit Input Map Settings Input map settings define logic values that are asserted with a voltage input to the inputs they are mapped. There are 12 binary inputs. To edit the binary input, select desired group number from the Group frame and the Input Map option in the Group View Frame. The available logic signals will appear in the Group Parameters text box. Select the appropriate variable, and then map to the desired input by selecting one or more inputs in the Input Map frame. It is recommended to set the input maps for all 8 setting groups. After editing the first group the Copy Group function can be used to copy the edited group to all other groups and then edit as required. This should be done after setting all logic, inputs and outputs for the first group. The inputs may also be inverted such that with no voltage applied the value of the signal mapped to that input is TRUE or logical 1. When voltage is applied the value is FALSE or logical 0. This is particularly useful when testing and may be used to simulate a voltage input. Group being edited I/O Logic Names Binary input or contact output # Input Inverter Help Information Comments Support Software 7-3

157 Edit Output Map Settings Output map settings define logic values that operate the output relays. There are 12 programmable output relays. To edit the output map, select the desired group number from the Group frame and the Output Map option in the Group View Frame. The available logic signals will appear in the Group Parameters text box. Select the appropriate variable, and then map to the desired output relay by selecting one or more outputs in the Output Map frame. It is recommended to set the output maps for all 8 setting groups. After editing the first group the Copy Group function can be used to copy the edited group to all other groups and then edit as required. This should be done after setting all logic, inputs and outputs for the first group. RELLOGIC-Programmable Logic Introduction The Programmable Logic program, RELLOGIC, is a REL 512 logic editor Programmable logic can be used to provide auxiliary protection, control and testing functions unique to the application. The programmable logic files are created off line, and uploaded to the relay via your communications program. Viewing the PLC Mapping from the relay s View I/O Mapping in the main menu will allow you to see which contacts are being controlled by the programmable logic. File Menu This menu selection allows you to create a new file, open an existing file, and save a file. From the File menu, versions 3.0 and above, you will have to select New REL512/Version 1.00to display the appropriate screen for editingprogrammable logic for the Version 1.0 platform. Group This menu selection allows you to select the programmable logic group to develop. There are 8 programmable logic groups, and each is associated with the respective settings and I/O mapping group. The group can also be selected on the Logic Categories This menu allows you to select the logic signals to be used in your PLC application. The logic signals available for programming are listed in Tables 7-1a and -1b. Each logic signal has two corresponding hexadecimal number identifies. A logic signal used in a program file that is loaded in the relay can be identified via the ASCII interface by one of the two hex numbers. The TRUE hex number represents the logic signal used in the normal state. The FALSE hex number shows that the logic signal has been inverted (NOT). Timer/Latch Unit This menu selection allows you to select the timer or latch control to be programmed. There are six timer units and two latch units. Logic Controls Timer Control Logic There are 6 Timer Control Logic schemes. Timer Control #1 is as shown in the figure below. Each scheme consist of 16 inputs (T111 - T144), 2 timer settings... pickup (T1PU) and dropout (T1DO), and up to 8 outputs (T1OUT, T2OUT,..., T8OUT). 7-4 Support Software

158 Each of the REL512 s defined signals under Logic Categories Menu can be assigned to any one input. Each output can be mapped to any number of the REL512 s programmable output relays. Timers can be set from 0 to 60 seconds in 10 ms increments. It should be noted, however, that the operating resolution is 40 ms. That is, the logic is tested every 40 ms Logic Signal Group, Timer Output Contact Pickup and Latch Control Logic There are 2 Latch Control Logic schemes. The latch unit can be set and reset. Latch Set Control #1 is as shown in the next figure. Each latch scheme consist of 16 set inputs (S111 - S144), 16 reset inputs (R111 - R144), and up to 8 outputs (T1OUT, T2OUT,..., T8OUT). Each of the REL512 s defined signals under Logic Categories Menu can be assigned to any one input. Each output can be mapped to any number of the REL512 s programmable output relays. Navigating between the latch set and reset screens is accomplished by clicking the Latch Reset Signal and Latch Set Signal boxes. Support Software 7-5

159 Table 7-1a. Programmable Signals Logic Categories Mappable Signals General TRUE (always 1) FALSE (always 0) Zone-1 Z1GT Z1PT Z1TRIP Zone-2 Zone-3 Forward Pilot ZONE 2 TRIP ZONE 3 TRIP PFGT PFPT PFT FWD PILOT TRIP Reverse Pilot PRGT PRPT PRT RVP PILOT TRIP OS and Load Restriction BLINDERS INNER SUPERVISED BLINDERS OUTER SUPERVISED OSB HS 50 Elements/Functions HS TRIP HS-N TRIP HS-P TRIP HS-Q TRIP MS 50 Elements/Functions 50 M SUPV PHASE 50 M SUPV 3PH 50 NM Supv 50 QM Supv MEDIUM SET GROUND TRIP MEDIUM SET NEGATIVE SEQUENCE TRIP LS 50 Elements/Functions 50 NL Supv 50 QL Supv 50 POL CURRENT LOWSET LOSS OF CURRENT ALARM 51 Trip Functions 51P TRIP 51Q TRIP 51N TRIP Other Current Functions CLOSE INTO FAULT TRIP STUB BUS Voltage Elements and Logic Functions UNDERVOLTAGE 3PH UNDERVOLTAGE 59N OVERVOLTAGE HS LOP BLOCK DIST Directional Elements FOWARD 3PH FORWARD GF REVERSE 3PH REVERSE GF 7-6 Support Software

160 Table 7-1b. Programmable Signals (continued) Logic Categories Mappable Signals Pilot Logic PILOT TRIP COMBINED PILOT CHANNEL START PILOT CHANNEL STOP CHANNEL RECEIVE ECHO KEY WEAKFEED KEY Fault Inception Detector FAULT INCEPTION DETECTOR FAULT INCEPTION DETECTOR I FAULT INCEPTION DETECTOR V High Speed Phase Selection Logic AG BG CG SLG FAULT Phase Selection at Fault/Trip AG FAULT BG FAULT CG FAULT AB FAULT BC FAULT CA FAULT ABG FAULT BCG FAULT CAG FAULT 3-PHASE FAULT Trip Signals DSP TRIP SINGLE POLE TRIP PHASE A SINGLE POLE TRIP PHASE B SINGLE POLE TRIP PHASE C TRIP 3-POLE Breaker Failure Logic BREAKER FAILURE INITIATE BREAKER FAILURE RETRIP BREAKER FAILURE TRIP Reclose Initiate and Block HSRI TDRI RECL BLOCK SINGLE POLE RECLOSE INITIATE BKR FAIL RB Binary Inputs INP1 INP2 INP3 INP4 INP5 INP6 INP7 INP8 INP9 INP 10 INP 11 INP 12 Support Software 7-7

161 Group, Timer and Latch Numbers Logic Signal Input Fields Output Contact Selection Latch Set and Reset Programming Group, Timer and Latch Numbers Logic Signal Output Contact Selection 7-8 Support Software

162 Programming the Relay Developing the Program File 1. Programming a timer or latch control is quite simple. Just follow the following simple steps. 2. Open or create a new file. 3. Select the group number to be programmed from Group Menu. 4. Select the timer or latch control to be programmed from Timer/Latch Menu. 5. Place the cursor in the appropriate input field to the AND gates. 6. From the Logic Categories Menu select the desired logic value. 7. Once the signal is selected and appears in the field, double click if you want it to be a negated input.. 8. Repeat the process until all input signals are defined. 9. If it is a timer unit set the on-delay and off-delay times by placing the cursor in the field and typing in the appropriate time. 10. If it is a latch unit be sure to set both latch set and latch reset units. 11. Select the desired output relays for each unit. 12. From the Help menu select Show Logic Signal Numbers to display hex number identifiers and change any input field. 13. Save the file from the File Menu. Loading ( sending file) to the Relay The following basic steps allow you to up load a programmable logic file to the relay. 1. Establish communications to relay in the normal manner using your communications program. 2. Access the relay s main menu and select [6] Password Functions. 3. Enter the correct password upon the prompt. The Password Functions Menu will appear. 4. Select [6] Send Programmable Logic to Relay. 5. Press <enter> when prompted. 6. You will then be prompted to start the transmission. Follow procedures defined by your commu nications program. 7. Select the programmable logic file and send it to the relay using Xmodem protocol. 8. Monitor the transmission to insure there are no errors. 9. When completed the relay will reboot. 10. After rebooting go to the Main Menu and select [4] View I/O Mapping, and then select a settings group number. 11. Select [6] View PLC Output Map and Timers. This will show the control unit map to the output relays for the selected group and the timer settings. 12. Select [7] View Input Mapping. This will show the hex number identifiers that are mapped to the AND gate inputs. 13. Check to see that all control outputs are mapped correctly. 14. Follow your test procedure to test your logic. Support Software 7-9

163 RELWAVE-Digital Fault Recording and Analysis Introduction The RELWAVE Digital Fault Recording and Analysis program is a tool to analyze, evaluate protection operations, and system performance. The program reads digital fault records recorded by the REL 512 during system disturbances. It records seven (7) analog channels and 176 relay operating elements, logic signals, and I/O digital (status) channels with ms resolution. There are two prefault and 14 post fault cycles of information for each record. If the fault is longer than 14 cycles, then additional records are stored for the event. The data is displayed graphically so that it can easily be analyzed. Among its many features are fault analysis, faulted phase identification, single and twoterminal fault location, vector displays, impedance plotting, harmonic analysis, report writing, and an industry standard Comtrade output file format. Data Display Windows Voltage and current oscillography Time scale ruler Control Panel Measuring unit and logic signal status Analog Window The analog quantities are displayed in this window as a function of time (cycles). The selection of the analog quantities can be made from the INIT button which opens the Analog Setup dialog box. This is discussed further in the Command Button Section. Time 0 indicates the fault inception point as determined by the relay. The time 0 point can be moved by clicking the left mouse button at the new location and selecting Edit/Set New Fault Location Menu Support Software

164 Digital Window 176 digital quantities are displayed in this window showing their status as a function of time. The line indicates TRUE or logical 1 (one) status. The leading edge (first sample point of the line) is TRUE (1) while the trailing edge (last sample point of the line) is FALSE (0). The displayed digital quantities can be selected or deselected from the main menu Digital selection. The selection of digital signals to be viewed can be made from the Digital Menu. This can be done by selecting the group of digital signals to be edited. The groups are identified and selected in the selection window. The individual signals (bits) are selected by checking the appropriate check box under the group name. Control Panel The control panel is located on the left side of the start-up window. It contains all the controls for the operation of the program, Following are descriptions of controls located on the control panel. CURSOR Frame When viewing oscillography this frame shows the position of the mouse cursor relative to the plot axis which it is over. The top field shows the voltage or current instantaneous value of the quantity plotted on that axis. The lower field shows the time in milliseconds (ms). DELTA Frame When viewing oscillography this frame shows the start, end and difference times in milliseconds between any two points selected with the Delta Option in the TASK Frame. Support Software 7-11

165 ZOOM Frame The Delta option in the Task frame must be selected for ZOOM to operate. With the cursor in the analog window, select the left boundary (plot From) of the new region to plot with the left mouse button. A vertical line marking the left boundary will appear. Select the right boundary (plot To) with the right mouse button. A vertical line marking the right boundary will appear. Select Zoom In to plot the new region. The boundaries are displayed in the From and To fields. You may Zoom In two levels, while you may Zoom Out only to the previous view. TASK Frame This frame shows the optional tasks that may be performed with when viewing oscillography. Delta Option This is the default option. This option allows you to measure the time difference between any two plot points. The start, end and difference times, are displayed in the DELTA Frame. To select the start point, locate the mouse cursor at the start point and press the left mouse button. To select the end point, locate the mouse cursor at the endpoint and press the right mouse button. Each time the left or right mouse button is pressed a new time will be displayed, which is the difference between the new and old (opposite to the mouse button pressed) times. Fault Option This option allows you to locate a one cycle region on which you can perform phasor calculations and fault location analysis. Locate the mouse cursor in the Analog Window at the beginning of the cycle to be analyzed and press the left mouse button. The Phasors & Fault Location Window will be displayed. This window provides the means to calculate phase and sequence phasors,, fault type and location based on the study region selected with the Fault Option on the Control Panel. The Compute command button will calculate the appropriate quantities and display them in the window. The Print Command Button will print data to the right of the analog quantities in the Analog Window and instruct the program to print the selected data when the RELWAVE report is printed Support Software

166 In the Faulted Phase Selection frame, you have the option to use the Relay s algorithm for phase selection or make the faulted phase selection yourself. The Positive Sequence Line Impedance and Zero Sequence Compensation frames show the data used to make fault location computations. This data is based on relay settings and is part of the down loaded REL file. It may be edited to evaluate possible new settings. The REL file also contains phasor quantities computed every sample. Each computation is based on the last 20 samples. You may use these or recompute them for comparison. Marker Option The Marker Option allows you to mark the plot at specific coordinates for NOTE references. Select the Marker Option, and then locate the mouse cursor at the desired location and press the left mouse button The point will be marked and labeled with a number in numerical order beginning with 1. You are allowed to mark up to 10 points. The notes will be printed on the right side of the plot and are available for printer output. The notes can be referenced for discussion in the report text available via the Text Command Button below. It is suggested that the Plot Option below be used to zoom in on the area of interest to be marked, mark the plots, and then be plotted back to desired size. This allows better resolution for the marked points. Also, the last point marked may be erased by pressing the space bar. Command Buttons Open This button displays the appropriate file dialog box for selecting fault recording (*.REL) files. This dialog box allows you to select the desired REL file from the Drive/Directory where the.rel files are stored. Once the Drive and Directory are selected, the available files are listed in the file box on the left. Point to the desired file with the mouse cursor and click to select the file. Init This button shows the Analog Setup Window that is used to select the analog quantities to be plotted. Select or deselect the appropriate quantities and click OK. Click Initialize to clear plot screen and replot. Support Software 7-13

167 Plot This button refreshes the analog plot box based on current information provided from either the Control Panel or Analog Setup Window. V (vector) This button displays a screen where phase and sequence quantities can be plotted on a vector diagram. Also displayed are digital quantities operated in the indicated time frame, where the vectors are computed. Print This button displays the Printer Window from which the document is printed, and/or the printer is setup. Copy This button copies the analog box image as viewed (without the Control Panel) to the Windows Clipboard from where it may be pasted into other Windows applications.? (Help) This button displays the HELP Window. Notes This button displays the Title/Text Window which can be used to develop text reports to be printed out with the oscillography. A Text File (FileName.TXT) with the same name as the DFR file (FileName.REL), except for the extension, is created for each REL file if not already present. The text file can be created in advance in Windows Notepad. The Title and Text information must be separated with a line where the first two characters are ** Support Software

168 The format is shown below: Title information (3 lines max.) ** Text information Exit This button allows you to gracefully exit the program. Ohms This button allow you to plot the impedance locus over a specified range of the fault record. Support Software 7-15

169 H (harmonic analysis) This button allow you to compute harmonic content over a specified range of the fault record. The Fault Record RELWAVE can read fault records generated with REL 512 firmware versions 1.24 and later. The fault record beginning with version 2.3 also contains the settings and programmable logic files. These related files are loaded into the folder where RELTOOLS is installed when a V2.3 file is opened in RELWAVE. These files are temp.txt, temp.bin, and temp.plc. Temp.txt is a text file containing the active group settings. Temp.bin is the binary settings file and can be opened in RELWISE. Temp.plc is the programmable logic file and can be opened RELLOGIC Support Software

170 Notes Support Software 7-17

171 Notes 7-18 Support Software

172 ABB REL 512 Line Protection and Breaker Terminal Reclosing This section provides detailed application, settings information and test procedures for the REL 512 reclosing function. This is an optional feature: instructions are applicable only if the reclosing expansion board has been provided. Application The large majority of overhead line faults is transient and can be cleared by momentarily de-energizing the line. It is therefor feasible to improve service continuity by automatically reclosing the circuit breaker after a fault operation. Usually the reclosing function is supervised by voltage checking, to verify one side of the breaker is isolated from the system, or by a synchronism checking function. Synchronism Checking Logic Synchronism-check is the logic used to ensure that a minimum impact occurs to the power system when a circuit breaker is closed. The driving force for current flow following breaker contact closure is the voltage appearing across the open contacts just prior to closing. The difference between the voltages on the two sides of the breaker is called the phasing voltage. The phasing voltage (V PHASING ) can be controlled by several methods. Two methods of synchronism checking are available in the REL 512; the conventional Angular and the more precise Phasing Voltage methods. Angular Synchronizing Characteristic The Angular method is the one most commonly used. The line-to-ground voltage (V BUS ) will provide a reference for the line relaying, and a comparison is made with an input voltage (V SYNC ) from the other side of the controlled breaker for relay sampling. It verifies the angular difference (V SYNC ) is within the acceptable range of ± SYNC ANGLE and verifies both voltage magnitudes are in the acceptable range between V MAX - V LIVE. The resulting synchronism region looks like an automobile windshield wiper stroke with V BUS at the center (see Figure 8-1). The required settings are SYNC CHAR, SYNC ANGLE, SLIP FREQ, MAX SYS V and LIVE VOLTAGE. Operation results when the synchronizing voltage (V BUS ) falls inside the synchronizing region and the slip frequency is below the set value of SLIP FREQ. Figure 8-1. Angular Synchronizing Characteristic Reclosing 8-1

173 Phasing Voltage Synchronizing Characteristic The Phasing Voltage method simply verifies the phasing voltage, V PHASING, is less than the phasing voltage setting PHASING VOLT. The Phasing Voltage is a vector computation of the voltage difference between the two voltages V BUS and V. Figure 8-2 describes the relationship required in order for SYNC closing of the circuit breaker to be permitted. The center of the circle is established by the reference voltage phasor (V BUS ). The radius of the circle is determined by the phasing voltage (V PHASING ) setting. Operation results when the synchronizing voltage (V SYNC ) falls inside the circle. A minimum and maximum level is established for the reference voltage. Outside this band, closing is not permitted, irrespective of the phasing voltage. A close output is produced in response to a reclosing directed synchronism check. The logic assures that synchronism which exists prior to tripping is not allowed to falsely indicate that synchronism exists following tripping. The synchronism-check function is intended to assure that the two segments of the power system that are to be interconnected by the closure of a breaker are in synchronism with a standing angle. It is not intended to provide an automatic synchronizing function for two systems that are operating at different frequencies. Note that a reclosing function must supervise the control by the synchronism-check action to prohibit any possibility of pumping of the breaker. Usually in conventional sync check relaying, a relatively long time measurement is used to insure that the voltages across the open breaker are in sync. However, this long time delay which may be 10 or more seconds, is undesirable if both ends of the line are being reclosed at high speed. If the time measurement is shortened, a faster sync check measurement can be made. However, this may result in reclosing for a non-synchronous condition with slip frequencies that are higher than desired for proper reclosing. A slip cutoff frequency function can provide a high-speed sync determination when voltages are in sync without the risk of reclosing if high slip frequencies are actually present. Setting the slip cutoff frequency setting SLIP FREQ to an acceptable level will assert sync as soon as the line angle reaches the sync window. Figure 8-2. Phasing Voltage Synchronizing Characteristic The sync check function will not provide an output to permit reclosing if no voltage is present on one or both sides of the open breaker via the voltage check function. With the possibility that either side of the breaker, bus or line, may be de-energized (dead), hot-bus-dead-line, dead-bus-hot-line, or deadbus-dead-line checks are necessary. In this case one or three phase voltages may be checked to establish clearly that the voltages are as they appear, and not possibly erroneous because of such things as fuse failure. 8-2 Reclosing

174 ABB REL 512 Line Protection and Breaker Terminal Breaker Monitoring The reclosing function allows monitoring the circuit breaker for several conditions. The total number of operations can be monitored with an alarm output when a set number of operations occur. Total operations are stored in nonvolatile memory. The circuit breaker can also be monitored for repetitive tripping and reclosing for a recurring fault. This may be hazardous to a circuit breaker, and therefore the number of operations allowed per set time period can be controlled. A recovery time can also be implemented to allow the circuit breaker to recover their full capability following a series of interruptions. Analog Outputs Eight analog outputs are available on the Reclosing Version 2.0 module. The outputs are as follows: Analog Output (1) Line-to-Ground Volt (Bus)1f Analog Output (2) Current 1f Analog Output (3) Watts 3f Analog Output (4) Vars 3f Analog Output (5) Fault Location Analog Output (6) Line-to-Ground Volt (Line)1f Analog Output (7) Synchronism Angle Analog Output (8) Slip Frequency Functional Specifications Reclosing Four programmable reclosing shots initiated by 52b and/or Reclose Initiate. Protection logic generated High Speed or Time Delay Reclose Initiate. Breaker state monitoring 52a/52b. Failed Reclose timing. Reclose Block capability. Hold Reclose Cycle capability. Follow Breaker Function. Maximum Cycle Timer. Close Pulse duration selectable. Synchronism Selectable single phase qualification. Selectable Phasing voltage or Angular synchronism qualification. Voltage Check with dead, live and max voltage qualification. Reclosing 8-3

175 Selectable single or three phase Voltage Check. External supervision qualification. Slip frequency qualification. Recloser Monitoring Cumulative Operations count for breaker service intervals. Breaker operations/time interval with selectable recovery time. Manual Close Phasing voltage or Angular qualification. External supervision qualification. Reclose Block capability. Binary Inputs Software selectable to 24, 48, 125 or 250vdc. Analog Outputs (Available with Reclosing Version 2.00 only.) The expansion module will have eight analog outputs which produce a scaled current derived by the measured voltages, currents, synchronism data, and fault location algorithm. Each output will be scaled as described below into 0-10 kw load. In addition the output (except Sync Angle ) must be capable of delivering 120% of full into a burden of 8.33 kw or less (reference 10 volts max). (1) Line Voltage, produces a scaled current representative of the line-to-ground voltage, from the protection logic, with the phase being selected by the setting. Voltage scaling is fixed volts full scale (0-1 milliampere) with the over range capability of 180 volts (1.2 milliamperes). (2) Current, produces a scaled current, from the protection logic, representative of the phase current selected by the setting. Current scaling is based on a nominal current range of 5 amperes as full scale (1 milliampere) with the over range capability of 6.0 amperes (1.2 milliamperes) for 5 amp CTs. Current range of 1 amperes as full scale (1 milliampere) with the over range capability of 1.2 amperes (1.2 milliamperes) for 1 amp CTs. (3 & 4) Watts & Vars, produces a scaled current representative of the 3 phase watts and vars from the protection logic. The real and reactive power outputs will be bipolar allowing receiving end (negative watts and vars). Real and reactive power scaling is based on 0-1,000 watts or vars, equal to full scale (0±1 milliamperes)with the over range capability will be 1,200 watts or vars (0±1.2 milliamperes) for 5 amp CTs. Power scaling is based on watts or vars, equal to full scale (0±1 milliamperes) with the over range capability will be 240 watts or vars (0±1.2 milliamperes) for 1 amp CTs. (5) Fault Location, the Line Length setting determines the scaling for the output. Full scale (1 milliampere) is the value of this setting, over range capability of (1.2 milliamperes). For example if the line length is set at 10 Miles, and the fault location algorithm determines a location of 5 miles, the output would be 0.5 milliamperes. (6) Bus Voltage, produces a scaled current representative of the line-to-ground voltage, from the reclosing logic, with the phase selected by the Line Voltage setting. Voltage scaling is fixed volts full scale (0-1 milliampere) with the over range capability of 180 volts (1.2 milliamperes). (7) Sync Angle, produces a scaled current representative of the synchronism angle as calculated in the reclosing/synchronism logic. Synchronism angle is the angle between the bus and line voltages. Sync Angle output will be bipolar allowing leading or lagging angular difference. The angle will be positive (0-(+1.0) milliampere) when the bus voltage leads the line voltage 0-(+180 ). The angle will be negative (0-(-1.0) milliampere) when the bus voltage lags the line voltage 0-(-180 ). 8-4 Reclosing

176 ABB REL 512 Line Protection and Breaker Terminal (8) Slip Frequency, produces a scaled current representative of the slip frequency as calculated by the reclosing/synchronism logic. Slip frequency is the rate of change of the sync angle. Slip frequency scaling is based on 0-1 hertz equal to 0-1 milliamperes. The over range capability will be 1.2 hertz equal to 1.2 milliamperes. Installation and Operation Reclose Module Rating and Tolerances Table 8-1. Analog Input Circuits Input Rating Voltage Rating (69 Wye/120V) Frequency 160 V continuous and 480 V for 10 seconds 60 Hz Table 8-2. Binary (Voltage) Input Circuits Input Burden 24 V dc > 0.16 VA 48 V dc > 0.16 VA 125 V dc > 0.44 VA 250 V dc > 0.44 VA Table 8-3. Binary (Contact) Output Circuits Circuit Voltage Trip Rating Continuous Rating Resistive Circuit Break Rating Inductive Vdc 30 A 8 A 50 W 15 VA 120 Vac 30 A 8 A 50 W 15 Va Control Power Requirements Refer to Table 1-4. Operating Environment Refer to Table 1-5. Reclosing 8-5

177 Installation Diagrams for Reclosing Version 2.XX External Connections Figure 8-3. System AC Voltage Phase-to-Ground Connections Connect single or three phase as required. For SYNC PHASE select Phase A, B or C as appropriate. Figure 8-4. System AC Voltage Phase-to-Phase Connections Connect single or three phase as required. For SYNC PHASE select PHASE A, B or C as appropriate. For example, a phase A connection would be A to VA and B to VAR and then select PHASE A for the SYNC PHASE setting. 8-6 Reclosing

178 ABB REL 512 Line Protection and Breaker Terminal Table 8-4. I/O Connections Function Terminal Block + DC - DC Chassis Ground TB6 0 Relay 8 (Close 1) TB6 1 2 Relay 7 (Close 2) TB6 3 4 Relay 6 (Lockout) TB6 5 6 Relay 5 (Failed Reclose) TB6 7 8 Relay 4 (Reclosing in Progress) TB Relay 3 (Cumulative Operations Alarm) TB Relay 2 (Synchronism/Voltage Check) TB Relay 1 TB Input 8 (52a) TB Input 7 (52b) TB Chassis Ground TB7 0 Input 6 (External Reclose Inititate 1) TB7 1 2 Input 5 (External Reclose Inititate 2) TB7 3 4 Input 4 (External Supervision) TB7 5 6 Input 3 (Manual Close Input) TB7 7 8 Input 2 (Hold Input) TB Input 1 (Drive to Lockout) TB VC, VCR (Bus Voltage) TB VCS, VCSR (Sync or Line Voltage) TB VB, VBR (Bus Voltage) TB VBS, VBSR (Sync or Line Voltage) TB Chassis Ground TB8 0 VA, VAR (Bus Voltage) TB8 1 2 VAS, VASR (Sync or Line Voltage) TB8 3 4 Analog Output 1 (Line Voltage - 1 f) TB8 5 6 Analog Output 2 (Current - 1 f) TB8 7 8 Analog Output 3 (Watts - 3 f) TB Analog Output 4 (Vars - 3 f) TB Analog Output 5 (Fault Location) TB Analog Output 6 (Bus Voltage - 1 f) TB Analog Output 7 (Synchronism Angle) TB Analog Output 8 (Slip Frequency) TB Reclosing 8-7

179 Reclosing and Synchronizing Reclose Settings and Application Synchronism and Voltage Check VOLT CHECK (Voltage Check Type) Voltage checking compares the voltages on each side of the breaker, bus and line, to insure the correct condition exist prior to reclosing. The checks are usually hot-bus-dead-line or dead-bus-hotline when synchronism checks are not employed. This setting allows the selection of one or three phase voltage checking. 1 PHASE provides the comparing of only one phase voltage on each side of the circuit breaker. If 1 PHASE selected, the phase selected by the SYNC PHASE setting is used for voltage checking. If 3 PHASE is selected all phase voltages are compared. Three phase voltages may be necessary to establish clearly that the voltages are as they appear, and not possibly erroneous because of such things as fuse failure. SYNC PHASE (Synchronism Phase Selection) This setting allows the selection of the phase that is to be used in establishing whether or not the system segments on two sides of a breaker are in synchronism. As an example, a single voltage transformer can be applied phase B to ground on the line side of the protected transmission line, and three phase bus voltage can be used for the line relaying. The setting PHASE B would then be chosen. Phase B-to-ground voltages would then be compared in making a synchronism check. SYNC CHAR (Synchronism Characteristic) Two fundamental choices are allowed for the shape of the characteristic that defines synchronism: the Angular (or wiper) method, or the Phasing Voltage (or circle) method. ANGULAR It s Operate area is defined by a voltage and angle difference (between the two voltages being compared for synchronism). The second voltage phasor must fall within the band defined by the voltage difference established by the settings MAX SYS V and LIVE VOLTAGE. The voltages must also have a phasor separation angle of no more than the SYNC ANGLE setting that is used. PHASING VOLT The phasing voltage is that voltage that appears across the controlled breaker contacts. It is the forcing voltage for current which flows following the closure of the breaker, and is therefore representative of the impact on the system following closure. The operating circle diameter is the maximum voltage to be allowed across the breaker for closing to be permitted (irrespective of phase angle). For any smaller phasing voltage, closing is allowed. The circle plot has the relay voltage at its center. If the head of the second phasor falls inside the circle, synchronism is indicated. SYNC ANGLE (Synchronism Angle) This setting applies only if the ANGULAR setting for SYNC CHAR is set. SYNC ANGLE is the maximum allowable angle difference between the voltages on each side of the circuit breaker in the tripped or open position just prior to closing. PHASING VOLTS (Phasing Voltage) This setting applies only if the PHASING VOLT setting for SYNC CHAR is set. PHASING VOLTS is the maximum voltage allowed across the circuit breaker open contacts just prior to closing. 8-8 Reclosing

180 ABB REL 512 Line Protection and Breaker Terminal SLIP FREQ (Maximum Slip Frequency) Though this function is not intended to provide an automatic synchronizing function, it may be used to supervise closing of a breaker where there is a very slow slip rate (as opposed to having absolute synchronism). A true automatic synchronizing function initiates closing ahead of synchronism, and takes into account breaker closing time so that the making of the breaker contacts occurs at exact synchronism. The slip frequency function examines the difference of frequency on the two sides of the breaker, and if it is below the setting, closing is allowed (under the supervision of the reclosing function). In general synchronism-check is intended to supervise closing of a breaker where the two system segments are tied together through another path than the one being closed, and only a standing angle is involved. MAX SYS V (Maximum System Voltage) This is the maximum possible operating system secondary voltage as seen by the relay. This will restrict reclosing with synchronism or voltage checking to normal voltage conditions. DEAD VOLTAGE (Dead System Voltage Threshold) This setting defines the maximum voltage level which may be considered de-energized, or dead. A setting of 10 volts or greater would be typical LIVE VOLTAGE (Live System Voltage Threshold) This setting defines the minimum voltage level which may be considered energized. A setting of 60 volts or less would be typical. Reclosing RECLOSING The setting allows the selection of the reclosing function. If reclosing is to be used set to ENABLE. NO OF RECLOSES (Number of Reclosures in Cycle) The reclosing cycle requires the choice of the total number of reclosures that are to take place before lockout occurs for a permanent fault. Any successful reclosure (into a sound line with no fault) produces reset and a reestablishment of the entire cycle. Settings for the individual reclose shots are defined later. RESET TIME DLY (Successful Reclose Reset Time Delay) This setting controls the time, following any reclosure, at which resetting of all reclosing functions takes place. This timer must be set longer than the longest tripping time that can occur, to avoid resetting during the time when the breaker is closed, but the relaying is timing for a trip. MAX CYCLE TIME (Maximum Reclose Cycle Time) This is a safety setting to assure that, irrespective of cause, the overall reclosing cycle time is not delayed excessively. This control may be incapacitated by selecting Infinite. Following the passage of the set time, further reclosing is blocked. FOLLOW BREAKER (Follow Breaker Function) This is an anti-pumping provision that is included to prohibit the number of reclosures from exceeding the number selected in a particular sequence, irrespective of the initiating source. The Enable settings recommended. Reclosing 8-9

181 FAILED RECLOSE (Failed Recloser Timer Enable) This timer is started by a reclose output. If breaker change of position is not acknowledged, through 52b switch opening, following initiation of reclosing, all reclosing is blocked and an alarm contact closes. The Enable setting is recommended. FAILED RECL TM (Failed Reclose Timer Setting) If Failed Reclose is enabled, a time must be chosen as a criterion for failure. A setting of approximately twice the normal closing time of the breaker should suffice. HOLD CYCLE (Hold Reclose Cycle at Input Point) This intermediate lockout function allows a last reclose shot to be held until synchronism is verified. This is useful for a breaker at a remote unattended substation to be finally closed automatically, but only after a fault has been cleared and synchronism has been confirmed. It allows a breaker at an attended station to be used to test a line to assure that a fault has been cleared. Recognition of synchronism closes the remote breaker. BREAKER STATE (Breaker Position Monitoring) A breaker 52b contact is closed when the breaker is open, and open when the breaker is closed. A 52a contact is closed when the breaker is closed, and open when the breaker is open. Two choices are allowed by setting, 52b only, or 52b and 52a. The second choice requires more wiring, but provides a supervision function based on complementary action of the two inputs. If both contacts are either open or closed at the same time, this input is classified as invalid, and no further reclosing takes place. 52A AND 52B TM (Breaker Position 52a and 52b Time Limit) During the breaker travel, opening or closing, there is a time during which both contacts are open. To prevent having an incorrect interpretation of this, a time setting is made, during which, no inconsistency is acknowledged. A setting equal to the nominal operating time of the auxiliary switch should suffice, such as 0.02 seconds. CLOSE PULSE (Breaker Close Pulse Duration) This function prevents the possibility of burning up the breaker closing coil when any malfunction prevents the breaker from closing following energization of the close circuit (also contacts of the breaker failure lockout auxiliary should open both the trip and close circuits. The close pulse must be long enough to assure that the breaker closes, even at reduced supply voltage, but not so long that the closing pulse is still present following the next high speed trip. Reclose 1 RC1 RI TYPE (Reclose 1 Reclose Initiate Type) This setting provides several choices for reclose initiation. The setting 52B allows reclosing only when the circuit breaker is determined to be open by the closure of the 52B contact. The setting RI requires a reclose initiate input from a tripping logic or external reclose initiate source. The settings 52A AND RI and 52A OR RI provide additional levels of security and dependability. RC1 BLOCK (Reclose 1 Block of Reclose) If blocking of the first reclosure is to be activated by out-of-step or other tripping select Enable Reclosing

182 ABB REL 512 Line Protection and Breaker Terminal RC1 DEAD TM (Reclose 1 Dead Time) This is the time that the circuit is de-energized to assure that the arc associated with a temporary fault is completely deionized. RC1 MAX WAIT (Reclose 1 Maximum Wait Time) The main function of this setting is to limit the time allowed for reclosing to occur, especially when waiting for synchronism-check to be satisfied. RC1 VOLT CHK (Reclose 1 on Voltage Check) If Hot-Line/Dead-Bus, Hot-Bus/Dead-Line or Dead-Bus/Dead-Line supervision of closing for the first reclosure is to be used, choose Enable. RC1 V CHK TYPE (Reclose 1 Voltage Check Type) If voltage closing is to be restricted to one combination only, select HBDL, HLDB or DBDL. The setting HBDL/HLDB will allow a close for either side hot and the other dead. RC1 SYNC CHK (Reclose 1 on Synchronism Check) If the first reclosure is to be supervised by internal synchronism check, select Enable. RC1 EXT SUPV (Reclose 1 on External Supervision) If the first reclosure is to be supervised by an external device, select Enable. Reclose 2 RC2 RI TYPE (Reclose 2 Reclose Initiate Type) This setting provides several choices for reclose initiation. The setting 52B allows reclosing only when the circuit breaker is determined to be open by the closure of the 52B contact. The setting RI requires a reclose initiate input from a tripping logic or external reclose initiate source. The settings 52A AND RI and 52A OR RI provide additional levels of security and dependability. RC2 BLOCK (Reclose 2 Block of Reclose) If blocking of the second reclosure is to be activated by out-of-step or other tripping select Enable. RC2 DEAD TM (Reclose 2 Dead Time) This is the time that the circuit is de-energized to assure that the arc associated with a temporary fault is completely deionized. RC2 MAX WAIT (Reclose 2 Maximum Wait Time) The main function of this setting is to limit the time allowed for reclosing to occur, especially when waiting for synchronism-check to be satisfied. RC2 VOLT CHK (Reclose 2 on Voltage Check) If Hot-Line/Dead-Bus, Hot-Bus/Dead-Line or Dead-Bus/Dead-Line supervision of closing for the second reclosure is to be used, choose Enable. Reclosing 8-11

183 RC2 V CHK TYPE (Reclose 2 Voltage Check Type) If voltage closing is to be restricted to one combination only, select HBDL, HLDB or DBDL. The setting HBDL/HLDB will allow a close for either side hot and the other dead. RC2 SYNC CHK (Reclose 2 on Synchronism Check) If the second reclosure is to be supervised by internal synchronism check, select Enable. RC2 EXT SUPV (Reclose 2 on External Supervision) If the second reclosure is to be supervised by an external device, select Enable. Reclose 3 RC3 RI TYPE (Reclose 3 Reclose Initiate Type) This setting provides several choices for reclose initiation. The setting 52B allows reclosing only when the circuit breaker is determined to be open by the closure of the 52B contact. The setting RI requires a reclose initiate input from a tripping logic or external reclose initiate source. The settings 52A AND RI and 52A OR RI provide additional levels of security and dependability. RC3 BLOCK (Reclose 3 Block of Reclose) If blocking of the third reclosure is to be activated by out-of-step or other tripping select Enable. RC3 DEAD TM (Reclose 3 Dead Time) This is the time that the circuit is de-energized to assure that the arc associated with a temporary fault is completely deionized. RC3 MAX WAIT (Reclose 3 Maximum Wait Time) The main function of this setting is to limit the time allowed for reclosing to occur, especially when waiting for synchronism-check to be satisfied. RC3 VOLT CHK (Reclose 3 on Voltage Check) If Hot-Line/Dead-Bus, Hot-Bus/Dead-Line or Dead-Bus/Dead-Line supervision of closing for the third reclosure is to be used, choose Enable. RC3 V CHK TYPE (Reclose 3 Voltage Check Type) If voltage closing is to be restricted to one combination only, select HBDL, HLDB or DBDL. The setting HBDL/HLDB will allow a close for either side hot and the other dead. RC3 SYNC CHK (Reclose 3 on Synchronism Check) If the third reclosure is to be supervised by internal synchronism check, select Enable. RC3 EXT SUPV (Reclose 3 on External Supervision) If the third reclosure is to be supervised by an external device, select Enable Reclosing

184 ABB REL 512 Line Protection and Breaker Terminal Reclose 4 RC4 RI TYPE (Reclose 4 Reclose Initiate Type) This setting provides several choices for reclose initiation. The setting 52B allows reclosing only when the circuit breaker is determined to be open by the closure of the 52B contact. The setting RI requires a reclose initiate input from a tripping logic or external reclose initiate source. The settings 52A AND RI and 52A OR RI provide additional levels of security and dependability. RC4 BLOCK (Reclose 4 Block of Reclose) If blocking of the fourth reclosure is to be activated by out-of-step or other tripping select Enable. RC4 DEAD TM (Reclose 4 Dead Time) This is the time that the circuit is de-energized to assure that the arc associated with a temporary fault is completely deionized. RC4 MAX WAIT (Reclose 4 Maximum Wait Time) The main function of this setting is to limit the time allowed for reclosing to occur, especially when waiting for synchronism-check to be satisfied. RC4 VOLT CHK (Reclose 4 on Voltage Check) If Hot-Line/Dead-Bus, Hot-Bus/Dead-Line or Dead-Bus/Dead-Line supervision of closing for the fourth reclosure is to be used, choose Enable. RC4 V CHK TYPE (Reclose 4 Voltage Check Type) If voltage closing is to be restricted to one combination only, select HBDL, HLDB or DBDL. The setting HBDL/HLDB will allow a close for either side hot and the other dead. RC4 SYNC CHK (Reclose 4 on Synchronism Check) If the fourth reclosure is to be supervised by internal synchronism check, select Enable. RC4 EXT SUPV (Reclose 4 on External Supervision) If the fourth reclosure is to be supervised by an external device, select Enable. Manual Close MANUAL CLOSE (Manual Close Supervision) Manual closing may be supervised by voltage and/or synchronism-check by selecting Enable. MC BLOCK (Reclose Block on Manual Close) If blocking of the manual close is to be activated by out-of-step or other tripping select Enable. MC MAX WAIT (Manual Close Maximum Wait Time) The main function of this setting is to limit the time allowed for closing to occur, especially when waiting for synchronism-check to be satisfied. Reclosing 8-13

185 MC VOLT CHK (Manual Close Supervision Voltage Check) If Hot-Line/Dead-Bus, Hot-Bus/Dead-Line or Dead-Bus/Dead-Line supervision of closing for the manual close is to be used, choose Enable. MC V CHK TYPE (Manual Close Voltage Check Type) If voltage closing is to be restricted to one combination only, select HBDL, HLDB or DBDL. The setting HBDL/HLDB will allow a close for either side hot and the other dead. MC SYNC CHECK (Manual Close on Synchronism Check) Enabling this function, permits a manual closure when synchronism exists between the two system segments being tied together by the breaker. MC EXT SUPV (Manual Close on External Supervision) If manual close is to be supervised by an external device, select Enable. Breaker Monitoring BREAKER LIMIT (Breaker Limit Function) Repetitive tripping and reclosing for a recurring fault may be hazardous to a breaker. If a restriction on the number of operations within a given period of time is desired, select Enable. TIME LIMIT (Breaker Function Time Limit) Breakers can have a certain number of operations within a fixed time before losing interrupting capability. This setting establishes a time limit for a group of faults and reclosures which are to be treated as a unit. Trip plus reclose is treated as an operation. OPER LIMIT (Breaker Operations Limit) This setting establishes a limit on the number of reclosures which are allowed within the TIME LIMIT (Breaker Function Time Limit). When the limit is reached, reclosing lockout is activated. RECOVERY TIME (Breaker Recovery Time) Some breakers require time to recover their full capability following a series of interruptions. This setting allows a time to be chosen, based upon the particular breaker being controlled. CUM OPER LIMIT (Breaker Reclose Cumulative Operation Limit) If the breaker is to be monitored for a total number of operations, to enunciate the need for maintenance, select Enable. NO OF CUM OPER (Number of Cumulative Breaker Operation Limit) This setting sets the number of breaker operations required for an alarm output when the setting is exceeded Reclosing

186 ABB REL 512 Line Protection and Breaker Terminal Input and Output Settings Binary Inputs VOLTAGE INPUT (Binary Input Voltage Level) This setting defines the input dc voltage that will be used to control reclosing. The settings are 24, 48, 125 or 250 V dc. Analog Outputs VOLTAGE PHASE (Voltage Output Phase Selection) This setting defines the phase, A, B, or C, that controls the analog voltage output. CURRENT PHASE (Current Output Phase Selection) This setting defines the phase, A, B, or C, that controls the analog voltage output. LINE LENGTH (Total Length of the Protected Line) This setting defines the scale for the line length in miles or kilometers. Settings Tables Synchronism and Voltage Check SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Sync-Check CHECK PROTECTION - BREAKER RECLOSING- [1] SYNC AND VOLTAGE VOLT CHECK Voltage Check Type - Three Phase or Single Phase 1 PHASE 1 PHASE, 3 PHASE ---- SYNC CHAR Synchronism Characteristic Type ANGULAR ANGULAR, PHASING VOLT ---- SYNC PHASE Synchronism Check Phase Selection for VOLT CHECK = 1 PHASE PHASE A PHASE A, PHASE B, PHASE C ---- SYNC ANGLE PHASING VOLT Maximum Phase Angle for SYNC CHAR = ANGULAR Maximum Phasing Voltage for SYNC CHAR = PHASING VOLT [1.0] DEG [1] VOLTS SLIP FREQ Maximum Slip Frequency [0.01] Hz MAX SYS V Maximum System Voltage [1.0] VOLTS DEAD VOLTAGE "Dead" Bus Threshold Voltage [1.0] VOLTS LIVE VOLTAGE "Live" Bus Threshold Voltage [1.0] VOLTS Reclosing 8-15

187 Reclosing SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN --MAX [INC R] CHOICE #1, #2, ETC. UNITS Reclose PROTECTION - BREAKER RECLOSING- [2] RECLOSING RECLOSING Reclosing DISABLE ENABLE, DISABLE ---- NO OF RECLOSES Number of Reclosures in Cycle [1] OPER RESET TIME DLY Successful Reclose Reset Time Delay [1.0] SEC MAX CYCLE TIME Maximum Reclose Cycle Time [1] 1000 = INFINITE SEC FOLLOW BREAKER Follow Breaker Function DISABLE ENABLE, DISABLE ---- FAILED RECLOSE Failed Reclose Timer Enable DISABLE ENABLE, DISABLE ---- FAILED RECL TM Failed Reclose Timer Setting [0.01] SEC HOLD CYCLE Hold Reclose Cycle at Input Point DISABLE ENABLE, DISABLE ---- BREAKER STATE Breaker Position Monitoring 52A/52B 52B, 52A/52B A AND 52B TM Breaker Position 52a and 52b Time Limit (only if 52A and 52B selected) [1] MILLISEC CLOSE PULSE Breaker Close Pulse Duration [10] MILLISEC Reclose Shots SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Reclose Shot #1 PROTECTION - BREAKER RECLOSING- [3] SHOT #1 RC1 RI TYPE Reclose 1 Reclose Initiate Type 52B 52B, RI, 52B AND RI, 52B OR RI ---- RC1 BLOCK Reclose 1 Block of Reclose DISABLE ENABLE, DISABLE ---- RC1 DEAD TM Reclose 1 Dead Time [0.1] SEC RC1 MAX WAIT Reclose 1 Maximum Wait Time [1] 1000 = INFINITE SEC RC1 VOLT CHK Reclose 1 on Voltage Check DISABLE ENABLE, DISABLE ---- RC1 V CHK TYPE Reclose 1 Voltage Check Type HBDL HBDL, HLDB, DBDL, HBDL/HLDB ---- RC1 SYNC CHK Reclose 1 on Synchronism Check DISABLE ENABLE, DISABLE ---- RC1 EXT SUPV Reclose 1 on External Supervision DISABLE ENABLE, DISABLE ---- SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Reclose Shot #2 PROTECTION - BREAKER RECLOSING- [4] SHOT #2 RC2 RI TYPE Reclose 2 Reclose Initiate Type 52B 52B, RI, 52B AND RI, 52B OR RI ---- RC2 BLOCK Reclose 2 Block of Reclose DISABLE ENABLE, DISABLE ---- RC2 DEAD TM Reclose 2 Dead Time [0.1] SEC RC2 MAX WAIT Reclose 2 Maximum Wait Time [1] 1000 = INFINITE SEC RC2 VOLT CHK Reclose 2 on Voltage Check DISABLE ENABLE, DISABLE ---- RC2 V CHK TYPE Reclose 2 Voltage Check Type HBDL HBDL, HLDB, DBDL, HBDL/HLDB ---- RC2 SYNC CHK Reclose 2 on Synchronism Check DISABLE ENABLE, DISABLE ---- RC2 EXT SUPV Reclose 2 on External Supervision DISABLE ENABLE, DISABLE Reclosing

188 ABB REL 512 Line Protection and Breaker Terminal SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Reclose Shot #3 PROTECTION - BREAKER RECLOSING- [5] SHOT #3 RC3 RI TYPE Reclose 3 Reclose Initiate Type 52B 52B, RI, 52B AND RI, 52B OR RI ---- RC3 BLOCK Reclose 3 Block of Reclose DISABLE ENABLE, DISABLE ---- RC3 DEAD TM Reclose 3 Dead Time [0.1] SEC RC3 MAX WAIT Reclose 3 Maximum Wait Time [1] 1000 = INFINITE SEC RC3 VOLT CHK Reclose 3 on Voltage Check DISABLE ENABLE, DISABLE ---- RC3 V CHK TYPE Reclose 3 Voltage Check Type HBDL HBDL, HLDB, DBDL, HBDL/HLDB ---- RC3 SYNC CHK Reclose 3 on Synchronism Check DISABLE ENABLE, DISABLE ---- RC3 EXT SUPV Reclose 3 on External Supervision DISABLE ENABLE, DISABLE ---- SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Reclose Shot #4 PROTECTION - BREAKER RECLOSING- [6] SHOT #4 RC4 RI TYPE Reclose 4 Reclose Initiate Type 52B 52B, RI, 52B AND RI, 52B OR RI ---- RC4 BLOCK Reclose 4 Block of Reclose DISABLE ENABLE, DISABLE ---- RC4 DEAD TM Reclose 4 Dead Time [0.1] SEC RC4 MAX WAIT Reclose 4 Maximum Wait Time [1] 1000 = INFINITE SEC RC4 VOLT CHK Reclose 4 on Voltage Check DISABLE ENABLE, DISABLE ---- RC4 V CHK TYPE Reclose 4 Voltage Check Type HBDL HBDL, HLDB, DBDL, HBDL/HLDB ---- RC4 SYNC CHK Reclose 4 on Synchronism Check DISABLE ENABLE, DISABLE ---- RC4 EXT SUPV Reclose 4 on External Supervision DISABLE ENABLE, DISABLE ---- Manual Closing SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Manual Close CLOSE PROTECTION - BREAKER RECLOSING- [7] MANUAL MANUAL CLOSE Manual Close DISABLE ENABLE, DISABLE ---- MC BLOCK Reclose Block on Manual Close DISABLE ENABLE, DISABLE ---- MC MAX WAIT Manual Close Supervision Maximum Wait Time [1] 1000 = INFINITE SEC MC VOLT CHK Manual Close Supervision Voltage Check DISABLE ENABLE, DISABLE SEC MC V CHK TYPE Manual Close Supervision Check HBDL HBDL, HLDB, DBDL, HBDL/HLDB ---- MC SYNC CHECK Manual Close on Synchronism Check DISABLE ENABLE, DISABLE ---- MC EXT SUPV Manual Close on External SYNC Supervision DISABLE ENABLE, DISABLE ---- Reclosing 8-17

189 Breaker Monitoring SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Breaker Operations Monitoring PROTECTION - BREAKER RECLOSING- [8] MONITORING BREAKER LIMIT Breaker Limit Monitoring DISABLE ENABLE, DISABLE TIME LIMIT Time Limit [1] SEC - OPER LIMIT Operations Limit [1] OPER - RECOVERY TIME Recovery Time [1] SEC CUM OPER LIMIT Breaker Reclose Cumulative Operation Limit DISABLE ENABLE, DISABLE ---- NO OF CUM OPER Number of Cumulative Operations [1] OPER Input/Output SETTING NAME ELEMENT, PARAMETER OR LOGIC NAME DEFAULT SETTING MIN--MAX [INCR] CHOICE #1, #2, ETC. UNITS Input/Output PROTECTION - BREAKER RECLOSING- [9] INPUT/OUTPUT VOLTAGE INPUT Binary Input Voltage Level , 48, 125, 250 VDC VOLTAGE PHASE Voltage Output Phase Selection VA VA, VB, VC ---- CURRENT PHASE Current Output Phase Selection IA IA, IB, IC LINE LENGTH Total Length of the Protected Line [0.1] MILES OR KM Reclosing Main Menu - Other Items MENU DESCRIPTION COUNTERS [A] INSPECT COUNTERS COUNTERS/ALARMS PROTECTION - BREAKER RECLOSING- [A] INSPECT Review cumulative operations counter. PROTECTION - BREAKER RECLOSING- [B] RESET [B] RESET COUNTERS/ALARMS - [1] CLEAR OPERATIONS COUNT - [2] RESET FAILED RECLOSE ALARM Clear cumulative operation counter or reset the latched failed reclose alarm. Clear cumulative operation counter. "Cumulative operation counter cleared." "Press any key to continue..." Reset the failed reclose alarm. "Failed reclose alarm reset." "Press any key to continue..." 8-18 Reclosing

190 ABB REL 512 Line Protection and Breaker Terminal Operating Logic Reclosing Logic Reclosing Sequence Reclosing logic is selected by the setting RECLOSING set to ENABLE. If the setting RECLOSING is set to DISABLE, the reclosing logic will do nothing even if initiated. The number of reclosing attempts, per event, is determined by the setting NO OF RECLOSES, which is set from 1 to 4. Each attempt, referred to as step(s) (or shots in the vernacular), has a setting selectable dead timer, ability to be blocked by a reclose block signal, and choice of sync and/or voltage checking supervision options. The following figures show an overview of a reclosing sequence and related supervisions and ancillary functions. Table 8-5. Reclosing Sequence Initialization Ready Dead Time Wait Upon power-up a self check routine is executed and logic enters Lockout state if setting RECLOSING set to ENABLE else go to Sleep state. In the Lockout state, if the breaker is closed, the logic enters Ready state after the reset time delay. Ready to start a reclosing sequence, waiting for initiation (initiation is setting dependent). Timer countdown of RC (n) DEAD TM timer setting (where n is 1-4, setting dependent). Waiting for a HBDL, HLDB or Sync-check condition (setting dependent). Close Issue close output to contact Outputs (7) and (8). Reset Lockout Sleep Timer countdown when resetting. If timer expires then return to Ready state. If another initiation occurs before timer expires, go to next Dead Time or Lockout (setting dependent). Lockout State entered after NO OF RECLOSES attempts have been attempted without successful reclose, binary Input (2) is energized or after failed reclose event. Reclosing disabled setting RECLOSE set to DISABLE or when settings change in progress. Execution of the reclosing logic must begin from the Ready State when either a reclose initiate signal is received from a functional input or an internal input. The internal and external reclose initiate inputs parallel each other. Binary input (7), 52b may also initiate reclosing logic if selected by setting RC (n) RI TYPE. Once the logic is initiated, the dead timer for the appropriate step begins to count down. The type of initiate input received by the logic determines the appropriate starting step. High speed reclose initiate (HSRI), binary input (6) or binary input (7) will initiate the Step 1, RC1 DEAD TM timer countdown. Time delay, internal reclose initiate (TDRI) or binary input (5) will initiate Step 2 RC2 DEAD TM. Reclosing 8-19

191 After the dead timer expires the logic checks if synchronism logic is enabled (SYNC VOLT CHK set to ENABLE). Synchronism logic must be enabled to use the internal supervision settings for sync and/ or voltage checking associated with each reclosing step. If SYNC VOLT CHK is set to ENABLE, the settings of RC (n) V CHK, RC(n) SYNC CHK must be evaluated. It is possible to have RC (n) V CHK, RC (n) SYNC CHK enabled at the same time since voltage checking involves either Side 1, Side 2 or both sides being de-energized or dead. Synchronism requires both sides to be energized which implies close can be supervised by volt or sync supervision since the two supervisions are mutually exclusive. If SYNC VOLT CHK is ENABLE and one or both of RC (n) V CHK and RC (n) SYNC CHK are enabled the RC (n) WAIT TIME timer starts and counts down after the dead time. During the wait time if one of the enabled conditions is satisfied, the close outputs Contact Output 7 and 8 are energized. If neither of the supervising conditions is met within the wait time, the reclosing logic goes to the LOCKOUT STATE. In addition to the internal voltage/sync check logic another setting which must be evaluated is RC (n) EXT SUPV set to ENABLE. If this setting is enabled the energization of binary input (4) is the equivalent of either voltage check or synchronism. When the close outputs are energized the reset timer (RESET TIME DLY) count down begins. If no additional initiate occurs during the reset time countdown, the reclose sequence is successful and the reclose logic will return to the READY STATE. If an another initiate occurs during the reset time, the reclosing logic will advance to the next step. The sequence will end with either a successful reclose or in the LOCKOUT STATE if an initiate occurs after the last programmed step before the reset time-out. Follow Breaker Logic The follow breaker logic, if enabled, will provide a 52b reclose initiate on the next breaker opening if a device external to the reclosing scheme closes the breaker during a reclosing sequence. The logic for FB 52B CLOSE is enabled when the breaker closes (52b opens) during the reclose cycle dead time and supervision time before a reclosing command is provided. It is disabled when the reclose command is provided and the circuit breaker is determined to be closed by 52b supervision. Even though FB 52B CLOSE logic is enabled, FB 52B CLOSE signal is only asserted when 52b is closed. This close and subsequent trip, if any, is counted as a reclose and will prevent more than the set number of reclosures. Synchronism and Voltage Check Logic The sync check function was developed to be applied on transmission lines. Normally, after all line terminal breakers trip to clear a line fault, one end of a line is closed first instantaneously or via a hotbus-dead-line check to energize the line. The other end(s) would close via a synchronism check. The sync check function is intended primarily for application where the two parts of a system are to be joined by the closure of a circuit breaker. These lines are interconnected at least at one other point in the system so that even though the voltages on either side of the open circuit breaker are the same frequency, there may be an angular difference due to load flow throughout the interconnected system. It is usually desirable to close the breaker even though an angular difference exists provided that the difference is not great enough to be detrimental to the system circuit breaker or system operation. Closing of the breaker is permitted when the angle across the open breaker remains in a fixed time period (little or no slip) and an acceptable angle is seen. Usually, in conventional sync check relaying, a relatively long time measurement is used to insure that the voltages across the open breaker are in sync. However, this long time delay which may be 10 to 20 seconds, is undesirable if both ends of the line are being reclosed at high speed. If the time measurement is shortened, a faster sync check measurement can be made, but this may result in reclosing for a non-synchronous condition with slip frequencies that are higher than desired for proper reclosing Reclosing

192 ABB REL 512 Line Protection and Breaker Terminal Figure 8-5. Reclosing Sequence Logic Diagram Reclosing 8-21

193 A slip cutoff frequency function is provided for high-speed sync determination when voltages are in sync without the risk of reclosing if high slip frequencies are actually present. Setting the slip cutoff to an acceptable level will sync as soon as the line angle reaches the sync window. The sync check function will not provide an output to permit reclosing if no voltage is present on one or both sides of the open breaker via the Live Bus / Line setting. Therefore for applications where Dead Line and/or Dead Bus operation is required, the dead voltage detection functions can be used. Selection can be for one or more of the following supervision conditions: 1. Hot Line/Dead Bus, HLDB Line Energized, Bus De-energized 2. Hot Bus/Dead Line HBDL Bus Energized, Line De-energized 3. Dead Line/Dead Bus Bus and Line De-energized Synchronism Check Reclose Criteria The following conditions must be satisfied for a synchronism check reclose: [S] SYNC VOLT CHK = ENABLED [S] RC (n) SYNC CHK = ENABLED (Bus V - Line V) Phase Angle < [S] SYNC ANGLE for time T SYNC, and [S] MAX SYS V > Bus V > [S] LIVE V BUS, and [S] MAX SYS V > Line V > [S] LIVE V LINE where: T SYNC = [S] SYNC ANG / ([S] SLIP FREQ * 180) Voltage Check Reclose Criteria Voltage checks are made on a basis of single or three phase voltage comparisons as determined by the setting VOLT CHECK. Where 1 PHASE is selected the phase that will be compared is selected with the SYNC PHASE setting. Where 3 PHASE is selected all three phases are compared. The criteria for defining three phase voltage levels is as follows: MAX SYS V is exceeded when any one-phase voltage on either side of the breaker exceeds the setting. LIVE V BUS (and 2) is live when all three-phase voltages exceed the LIVE VOLTAGE setting. DEAD V BUS (and 2) is dead when all three-phase voltages are below the DEAD VOLTAGE setting. The following conditions must be satisfied for a voltage check reclose: (For reference Side 1 is bus side.) [S] SYNC VOLT CHK = ENABLE [S] RC (n) VOLT CHECK = ENABLE and the following [S] RC (n) V CHK TYP: HBDL (Hot Bus - Dead Line) Bus V > [S] LIVE V BUS, and Line V < [S] DEAD V LINE HLDB (Hot Line - Dead Bus) Line V > [S] LIVE V LINE, and Bus V < [S] DEAD V BUS DBDL (Dead Bus - Dead Line) Bus V < [S] DEAD V BUS, and Line V < [S] DEAD V LINE 8-22 Reclosing

194 ABB REL 512 Line Protection and Breaker Terminal HBDL/HLDB (Hot Bus - Dead Line or Hot Line - Dead Bus) Bus V > [S] LIVE V BUS, and Line V < [S] DEAD V LINE or Line V > [S] LIVE V LINE, and Bus V < [S] DEAD V BUS External Supervision Reclose Criteria The following conditions must be met for an external supervision reclose: RC (n) EXT SUPV = ENABLE and binary input (4) EXT SUPV is asserted (voltage is applied). Manual Close Function Manual close logic is commonly considered a part of the sync-check or voltage check logic and is provided to allow a sync or voltage check supervised closing of circuit breaker. Essentially the manual close logic is to allow the user access to the sync-check and or voltage check logic to supervise the operator control switch closure of a circuit breaker. Figure 8-7 shows the Manual Close logic flow. The following conditions must be met for a manual close operation: [S] MANUAL CLOSE = ENABLE and binary input (3) MANUAL CLOSE INPUT is asserted (voltage is applied) or MANUAL CLOSE signal is sent from the protection logic. MANUAL CLOSE signal is generated when utilizing the protection logic Breaker Control function [3] Close Breaker with Supervision. Contact outputs (7) CLOSE 2 and (8) CLOSE 1 operate if [S] MC VOLT CHK, and/or MC SYNC CHK, and/or MC EXT SUPV are satisfied. These criteria will be evaluated as described above. Reclosing must be enabled to use the manual close function. Reclosing 8-23

195 Figure 8-6. Reclose Supervision Logic Diagram 8-24 Reclosing

196 ABB REL 512 Line Protection and Breaker Terminal Figure 8-7. Manual Close Logic Diagram Reclosing 8-25

197 Breaker Monitoring Logic The total number of circuit breaker operations can be monitored with an alarm output when a set number of operations occur by setting CUM OPER LIMIT to ENABLE, and NO OF CUM OPER to the desired maximum number of operations before alarm. The circuit breaker can also be monitored for repetitive tripping and reclosing for a recurring fault by setting BREAKER LIMIT to ENABLE. The number of operations allowed per set time period is controlled by setting TIME LIMIT and OPER LIMIT. A recovery time can also be implemented to allow the circuit breaker to recover their full capability following a series of interruptions by setting RECOVERY TIME. Figure 8-8. Breaker Monitoring Logic Diagram 8-26 Reclosing

198 ABB REL 512 Line Protection and Breaker Terminal Acceptance and Maintenance Tests This specification is an abbreviated test of the reclosing and synchronism logic to be used only with reclosing module assembly 1619C38G01. Equipment required: 1) Computer with an available serial communications port and TTY compatible software i.e. Windows terminal, HyperTerminal or Crosstalk. 2) AC voltage source with dual output, phase variable and independent frequency control to test slip. 3) DC power supply. 4) Switches to apply dc voltage to the binary inputs. 5) Indicators to monitor the dry contact outputs listed below. 6) Relay with electrically operated trip and reset coils to simulate the breaker (will be referred to as the breaker for test purposes). Setup With the power off, connect the following circuits. 1) Connect a common dc ground to each of - term. listed for each contact output, binary input and relay power listed in the next table. 2) Connect dc + through a normally open contact on the breaker to 52b+ on the recloser. 3) Connect dc + through a normally closed contact on the breaker to 52a+ on the recloser. 4) Connect dc + through the reset coil on the breaker to the Close 1+ contact. 5) Connect dc + through a switch to the trip coil on the breaker. 6) Connect dc + through a switch to binary inputs 1-6+ on the recloser, as required in each test step. 7) Connect dc + through an indicator to contact output 2-6+ on the recloser. Preparation for Testing the Reclosing Module Connect the front communication cable. The communication baud rate should be set to Apply power to the breaker, then energize the relay. Upon power-up the self-check routine is executed and logic enters sleep state. The SELF TEST LED should be flashing and RECLOSING IN SERVICE LED should be off. Change the following settings in group 8. [2] Reclosing Reclosing Enable Enable Reset Time Delay 10 Failed Reclose Timer Enable Enable [3] Shot 1 Reclose Initiate Type 52b or RI [4] Shot 2 Reclose Initiate Type 52b or RI Copy Protection & I/O Map Settings from group 8 to the active group 1.The recloser will reset, then enter the Lockout state, the front panel LOCKOUT and RECLOSING IN SERVICE LEDs will turn on. Also the LOCKOUT relay indicator will turn on. After a few seconds the lockout condition will clear and the recloser will return to the Ready state. Reclosing 8-27

199 Table 8-6. Rear Connector Assignments (Reclosing Option Only) Function Terminal Block + Term - Term Relay Power TB1 V+ V- Contact Output (8) Close 1 TB6 1 2 Contact Output (7) Close 1 TB6 3 4 Contact Output (6) Close 1 TB6 5 6 Contact Output (5) Close 1 TB6 7 8 Contact Output (4) Close 1 TB Contact Output (3) Close 1 TB Contact Output (2) Close 1 TB Contact Output (1) Close 1 TB Binary Input (8) 52a TB Binary Input (7) 52b TB Binary Input (6) External Reclose Initiate 1 TB7 1 2 Binary Input (5) External Reclose Initiate 2 TB7 3 4 Binary Input (4) External Supervision TB7 5 6 Binary Input (3) Manual Close Input TB7 7 8 Binary Input (2) Hold Input TB Binary Input (1) Drive to Lockout TB VC, VCR (Bus Voltage) TB VCS, VCSR (Synch Voltage - Line) TB VB, VBR (Bus Voltage) TB VBS, VBSR (Synch Voltage - Line) TB VA, VAR (Bus Voltage) TB7 1 2 VAS, VASR (Synch Voltage - Line) TB Reclosing

200 ABB REL 512 Line Protection and Breaker Terminal Input and Output Tests Voltage Check Apply 70vac to VAS (line). At this time the front panel The front panel HLDB led will be on. Remove the applied voltage to VAS and reapply to VA (bus). The HLDB led will extinguish and the front panel HBDL led will turn on. Change and save the following setting to active group 1. [1] Sync and Voltage Check Sync Phase Selection B Apply 70vac to VBS (line). At this time the front panel The front panel HLDB led will be on. Remove the applied voltage to VBS and reapply to VB (bus). The HLDB led will extinguish and the front panel HBDL led will turn on. Change and save the following setting to active group 1. [1] Sync and Voltage Check Sync Phase Selection C Apply 70vac to VCS (line). At this time the front panel The front panel HLDB led will be on. Remove the applied voltage to VCS and reapply to VC (bus). The HLDB led will extinguish and the front panel HBDL led will turn on. Sync Check Apply 70vac to VA (bus). Apply a second 70vac voltage with a 10 degree phase shift to VAS (line). At this time the front panel SYNC CHECK led and SYNCHRONISM CHECK output indicator will be on. Increase the phase shift to 21 degrees the indicators will turn off. Breaker Control Momentarily activate External Reclose Initiate 1 switch and the Reclosing In Progress relay turns on. The recloser will enter into the first reclose sequence, and 0.5 second later Close 1 & 2 indicators will turn on for 100 msec. Before the 10 second reset time expires, momentarily activate External Reclose Initiate 2 switch. The recloser will enter into the second reclose sequence and activate Close 1 & 2 indicators 0.5 second later. Before the 10 second reset time expires, trip the breaker. The recloser will go to lockout and the front panel LOCKOUT led and LOCKOUT relay will turn on. Also the Reclosing In Progress relay will turn off. Reset the breaker and the recloser will return to the ready state. The LOCKOUT indicator will turn off once the Reset Time Delay of 10 seconds has expired. Failed Reclose Disconnect the lead going to the close coil of the breaker. Trip the breaker and the recloser will enter into the first reclose sequence, and 0.5 second later attempt to close the breaker. Since the 52b signal remains, the recloser will enter into the Failed Reclose Timer. The close outputs will be energized for 2 seconds and the recloser will go to failed reclose lockout. The LOCKOUT led, LOCKOUT and FAILED RECLOSE indicators will turn on. Reconnect the lead going to the reset coil of the breaker, manually close the breaker, and the recloser will return to the ready state. The LOCKOUT indicators will turn off once the Reset Time Delay of 10 seconds has expired. The FAILED RECLOSE indicator will remain latched. To clear FAILED RECLOSE indicator enter the menu item. [B] Reset Counters/Alarms [2] Reset Failed Reclose Alarm Reclosing 8-29

201 Manual Close/External Supervision Change and save the following settings to active group 1. [2] Reclosing Breaker Monitor Position 52b [7] Manual Close Manual Close Enable Enable External Supervision Enable Enable Trip the breaker, the recloser will enter into the first reclose sequence and 0.5 second later Close 1 & 2 indicators. Before the 10 second reset time expires, trip the breaker. The recloser will enter into the second reclose sequence and turn on Close 1 & 2 indicators 0.5 second later. Before the 10 second reset time expires, trip the breaker. The recloser will go to lockout and the front panel LOCKOUT led and LOCKOUT relay indicator will turn on. Momentarily activate Manual Close Input switch the recloser. Within the manual reclose wait time of 300 seconds activate External Supervision switch, which will close the breaker and the recloser to the ready state. Drive to Lockout and Hold Change and save the following setting to active group 1. [2] Reclosing Hold Reclose Cycle Enable Enable Activate Drive To Lockout switch and the recloser will go to lockout and the front panel LOCKOUT led and LOCKOUT indicator will turn on. Deactivate Drive To Lockout switch and before the 10 second reset time expires, activate Hold Input switch. The recloser will hold indefinitely. Deactivate the Hold Input switch and LOCKOUT indicator will turn off once the remaining portion of the Reset Time Delay has expired. Cumulative Operations Alarm Change and save the following settings to active group 1. [8] Monitoring Cumulative Operations Enable Enable Cumulative Operations Limit 1 [B] Reset Counters/Alarms [1] Clear Cumulative Operations Count Trip the breaker, the recloser will enter into the first reclose sequence, and Close 1 & 2, and Cumulative Operations Alarm indicators will turn on. [B] Reset Counters/Alarms [1] Clear Cumulative Operations Count Test Finalization This ends the tests as it pertains to general reclosing applications. The tests in section 5 & 6 apply to customer specific applications. Return the relay to the default settings Copy Protection & I/O Map Settings from group 2 to 8 and group 2 to Reclosing

202 ABB REL 512 Line Protection and Breaker Terminal Analog Outputs The analog current outputs are three different types: 1) Outputs 1, 2, 5, 6 and 8 (0-1ma) with 20% over range capability. 2) Outputs 3 and 4 (0±1 ma) with 20% over range capability. 3) Output 7 (0±1.0 ma). Setup With the power off, connect a 1K ohm 1% ¼ watt load resistor for each of the 8 analog outputs. A voltmeter will be necessary to measure analog output voltage. Connect the three-phase system AC current and voltages to terminal block TB2. Change and save the following settings to active group 1. [7] Manual Close Manual Close Enable Enable Synchronism Check Enable Enable Table 8-7. Analog Output Functions (Analog Output) Function Terminal Block + Term - Term (1) Line-to-Ground Volt (Line) 1 TB8 5 6 (2) Current 1 TB8 7 8 (3) Watts 3 TB (4) Vars 3 TB (5) Fault Location TB (6) Line-to-Ground Volt (Bus) 1 TB (7) Synchronism Angle TB (8) Slip Frequency TB Testing Analog Outputs The referenced quantities are for 5 amp CTs, 1 amp CTs quantities are in parenthesis. Analog Output (1) Line-to-Ground Volt (Line)1f Apply 75 vac to phase A system AC voltage input. The voltage across the resistor should be 0.50 vdc ± 2%. Remove the applied voltage. Analog Output (2) Current 1f Apply 2.5 amp (0.5 amp) to phase A system AC current input. The voltage across the resistor should be 0.50 vdc ± 2%. Remove the applied current. Reclosing 8-31

203 Analog Output (3) Watts 3f Apply balanced 3 phase 75 vac to system AC voltage inputs. Apply balanced 3 phase 2.22 amp (0.44 amp) to system AC current inputs. Each phase voltage and current should have a phase shift of 0 degrees. The voltage across the resistor should be 0.50 vdc ± 2%. Analog Output (4) Vars 3f With the balanced 3 phase voltage and current inputs still applied from the previous test shift each current phase +90 degrees from it s respective voltage. The voltage across the resistor should be 0.50 vdc ± 2%. Remove all applied voltages and currents. Analog Output (5) Fault Location Adjust the maximum fault distance setting to be double the expected fault distance. Apply a single phase A to ground fault to the relay. Observe the fault distance is shown is consistent with the measured output value. Analog Output (6) Line-to-Ground Volt (Bus)1f Apply 75 vac to reclosing phase A bus voltage input. The voltage across the resistor should be 0.50 vdc ± 2%. Analog Output (7) Synchronism Angle Apply 75 vac to reclosing phase A line voltage input shift of 75 degrees leading. The voltage across the resistor should be 0.50 vdc ± 2%. Remove the applied voltages. Analog Output (8) Slip Frequency A slip cutoff frequency function is provided for high-speed sync determination when voltages are in sync without the risk of reclosing if high slip frequencies are actually present. Testing this output function requires an automated test generator capable of changing frequency of the bus voltage while keeping the line voltage frequency fixed. The rate of change of frequency must also be controllable. Breaker Control Functions Setup To operate the unsupervised control functions, these parallel breaker control connections must be made. Connect them as shown in the four +- terminal groups. Analog Output Function Terminal Block + Term - Term Binary Input (7) 52b Input 4 (Programmable) TB6 TB Contact Output (8) Close 1 Relay 4 (Programmable) TB6 TB Reclosing

204 ABB REL 512 Line Protection and Breaker Terminal Then update the following settings: [8] Configure Output Maps [2] Logic Signals Network 52 Close Map to 4 [1] Modify Input Map [9] Configure Input Maps Breaker 1 Open 52b Map to 4 Breaker 2 Open 52b Map to 4 Breaker Open The following Password Functions commands will open the breaker. <select> [A] Breaker Control <select> [1] Open Breaker <response> YOU ARE ABOUT TO OPEN THE CIRCUIT BREAKER(S). <response> Press Y to OPEN the breaker(s). <response> Press any other key to ABORT. <select> Y <response> Opening Breaker(s) SUCCESS <response> Press any key to continue. <select> / Breaker Close The following Password Functions commands will close the breaker without supervision. <select> [2] Close Breaker <response> YOU ARE ABOUT TO CLOSE THE CIRCUIT BREAKER(S) WITHOUT SUPERVISION. <response> Press Y to CLOSE the breaker(s). <response> Press any other key to ABORT. <select> Y <response> Closing Breaker(s) SUCCESS <response> Press any key to continue. <select> / Breaker Close with Supervision Apply 70 vac to reclosing phase A line voltage input and 70 vac to phase A bus voltage input with phase shift of 15 degrees leading. Repeat step 6.2 to open the breaker. The following Password Functions commands will close the breaker with supervision. <select> [3] Close Breaker with Supervision <response> YOU ARE ABOUT TO CLOSE THE CIRCUIT BREAKER(S) WITH SUPERVISION. <response> Press Y to CLOSE the breaker(s). <response> Press any other key to ABORT. <select> Y Reclosing 8-33

205 <response> Closing Breaker(s) SUCCESS <response> Press any key to continue. <select> / Increase the phase shift to 21 degrees leading and repeat this test. The breaker will not close. Test Finalization This concludes the testing. Remove all voltages applied to the relay. Return the relay to the default settings Copy Protection & I/O Map Settings from group 2 to 8 and group 2 to 1. Maintenance The protection terminal and reclosing module are self-supervised. No special maintenance tests are required. However, company directives for maintenance of the power system should be followed and in this respect, the REL 512 can be regarded as a standard relay device in your system Reclosing

206 ABB REL 512 Line Protection and Breaker Terminal Notes Reclosing 8-35

207 Notes 8-36 Reclosing

208 REL 512 Instruction Pointer Substation Automation and Protection Division REL 512 Firmware Upgrade Introduction As new firmware releases are made available for the various firmware modules of the REL 512, your existing relay may be upgraded from your PC using a simple and inexpensive parallel interface to the relay. This note discusses the software requirements and how to use the interface to upgrade the REL 512 firmware to new version releases. Parallel Interface Module The interface modules and cables defined in Figure 1 are required for the parallel connection of the computer to the relay s main, reclosing, or network board, depending on the firmware to be loaded. Figure 1. Parallel Interface Module and Connections

209 REL 512 Firmware Upgrade There are three boards (modules) to program with new firmware. The availability of each board depends on the relay s configuration (options). The boards to be programmed are: Main Board, #1 or #2 (protection functions) Reclosing Board, #1 or #2 (reclosing functions) DNP Board (network communications) Figures 2 and 3 show the locations and connector (jack) number... J47, J90, J5 and JP14, of each board connector to which the 10-pin BDM interface must mate. Main Board #1 The 10-pin connector for the main board #1 is J47 and is located on the main board in front of the large CPU. If the reclosing board is attached connector J47 is not accessible and the main board 10-pin programming connector is J9 on the right front of the reclosing board and is identified as the main board programming port. Main Board #2 The 10-pin connector for the main board #2 is J90 and is located on the left front of the main board. This connector is accessible with the reclosing board attached and must be used to program the main board. If the reclosing board is attached do not use the main board programming port that is located on the reclosing board. Reclosing Board, #1 and #2 The 10-pin connector for the reclosing board is J5 on the left front of the reclosing board and is identified as the 331 processor programming port. DNP Board The 10-pin connector for the DNP board is JP14 and is located on the front of the DNP board. If the reclosing board is installed the connector will be on the left side under the reclosing connector recessed about two inches. Making the Connection As you face the relay, pin 1 of the main and reclose connectors are to the right. Make sure the red side of the ribbon cable is also to the right when making the connection. Pin 1 of the DNP connector is to the left. Make sure the red side of the ribbon cable is also to the left when making the connection. Firmware As previously stated there are up to three boards to upgrade with new firmware, each requiring individual programming. Upgrades are executed from Windows and are made separately to the main board, the reclosing board and the network board. The downloadable firmware files for each board are provided in files with.s19 file extensions. The files for each board are described in Table 1. 2

210 REL 512 Firmware Upgrade Figure 2. Connections to the Relay for Different Board Configurations Using Main Board #1 Figure 3. Connections to the Relay for Different Board Configurations Using Main Board #2 3

211 REL 512 Firmware Upgrade Table 1. Files required for loading New Firmware. Main Board #1 Main Board #2 Reclosing Board #1 Reclosing Board #2 DNP MnabvXXX MnabvXXX Rcl1vXXX Rcl2vXXX Dnpvxxx.s19.s19.s19.s19.s19 A = 5-50 Hz A = 5-50 Hz XXX Hz 6-60 Hz Version B = 1 1 A B = 1 1 A 5 5 A 5 5 A XXX Version XXX Version XXX - Version XXX - Version Description This is new firmware that is to be loaded on the main board and is provided with a file name that identifies the new version number and applicable rating information... frequency, CT input. (XXX = 220 = version 2.20) NOTE: Versions of 2.00 and higher for the Main Board will run only on Main Board #2. NOTE: Versions of 2.00 and higher for the Reclosing Board will run only on Reclosing Board #2. MnABvXXX. cfg A = 5-50 Hz 6-60 Hz B = 1 1 A 5 5 A XXX - Version MnABvXXX. Rcl1vXXX.cf Rcl2XXX.cfg DnpvXXX.cf cfg g g A = 5-50 Hz 6-60 Hz B = 1 1 A 5 5 A XXX Version XXX - Version XXX - Version XXX - Version This is a configuration file that calls *.32p and *.s19 files. It may need to be edited to the.s19 file name above (XXX = 220 = version 2.20) NOTE: Versions of 2.00 and higher for the Main Board will run only on Main Board #2. NOTE: Versions of 2.00 and higher for the Reclosing Board will run only on Reclosing Board #2. Main1.32p Main2.32p Recl1.32p Recl2.32p Dnp.32p This is a flash program file for the boards CPU processor. If a different file name is used then configuration file (*.cfg) will need to be modified accordingly. Editing the Configuration File There are three files associated with upgrading the firmware on any one of the relay s processing boards. There are also several types of files available, as identified in Table 1 that address different applications and relay options. Each user only needs those files that apply to his or her system and application. For example, a U.S. user will only need main board files for 60 Hz and 5 ampere applications. These files for firmware v2.11 are Mn65v211.cfg, Mn65v211.s19 and Main2.32p, and are the only files required for upgrading a version 2 main board. If upgrading a reclosing board # 2 with reclosing V2.0 firmware, the files needed are Rc12v200.cfg, Rc12v200.s19, and Rec12.32p. Normally, editing any of these files is not required, but it may be on that rare occasion that reviewing or editing the configuration file may solve an issue. It should be noted that only the configuration (*.cfg) file should ever be edited. The firmware (*.s19) file is the new firmware that is being installed and the platform (*.32p) file provides instructions to the CProg32W programmer for how to 4

212 REL 512 Firmware Upgrade install the firmware file in the platform s EPROM. The main relay board #2 configuration file Mn65v211.cfg (60 Hz and 5 A) has the following format: RE CM \REL512\PLATFORM\MAIN2.32P 0 RE CM \REL512\PLATFORM\MAIN2.32P 0 SS \REL512\60HTZ_5A\Ver2.11\MN65V211.S19 EM PM VM QU The configuration file must clearly define where the program (main2.32p) and firmware (mn65v211.s19) are located. CPROG32W Installation Before beginning remove any previous P&E Micro program files that were provided to install REL 512 firmware. Insert the floppy disk with Prog32w 95,98,NT Version 1.08.exe on it into your floppy drive. Using Explore (Press the Key with the windows symbol on it and E simultaneously) copy that file to a Temporary directory (any directory is sufficient) on your Computer (drive C: or D:). Change to the drive you just copied the EXE file to and double click on it to start it. Follow instructions to install the files and use the default installation directory. After installing you will then have to install the NT driver on your computer. The NT driver needs to be installed if you are using 95, 98, or NT operating systems. If you have an NT system read the How to Install NT Driver file. This utility along with the associated files will be extracted and put on your computer but, will have to be run separately. Read the TXT files that are supplied during the installation for more information. This Step can be skipped if CPROG32W is already INSTALLED on you Computer. Go on to next section. Program File Installation Insert the floppy disk with MAIN Board label on it into your floppy drive. Select RUN from the START menu. Type in A:\SETUP and select OK. The SETUP.BAT program will install the Firmware in the correct directory automatically. If you receive the files over there are two options. The first is to copy the files RELXXX.exe and Setup.bat to a floppy disk and follow the procedure above. The second option is to create in the Root directory on C drive a folder/directory called REL512 and copy the RELXXX.exe to C:\REL512. XXX Is the Version number of REL512 Main code you are trying to install. Next open a DOS session and change directories to C:\REL512 type CD \REL512 and you will be placed there. Next type the command at the prompt: RELXXX d [ENTER]. Note: the d must be lower case. This will unzip and create the directory tree needed. Note: the directory tree must not be altered otherwise attempting to program any board on the REL512 will FAIL. 5

213 REL 512 Firmware Upgrade After installation find the directory that CPROG32W.EXE is located in (C:\PEMICRO) and right click on it and select Create Shortcut. Then right click on the shortcut just created select copy and then go to Your desktop and place the shortcut there. The Desktop should now contain the shortcut just copied. Loading the Firmware The following procedure is recommended to reliably load the firmware: IMPORTANT: IT IS RECOMMENDED THAT YOU DOWNLOAD THE SETTINGS FROM THE REL512 BEFORE UPDATING THE RELAY. 1. Download the REL512 settings. Select Retrieve data from the REL512 Root Menu. 2. Select Receive settings from Relay. Then download the settings using the terminal emulator. 3. If you have any Waveform files that you need to save you will need to download them at this time also. 4. From the Root Menu select View Product Information. And note the Settings Database Version number. For later reference. 5. De-energize the REL 512 to be upgraded. 6. Remove the front panel and disconnect the LCD display (UI) cable. Set the front panel aside. WARNING: DO NOT CONNECT OR DISCONNECT THE FRONT PANEL LCD DISPLAY WHILE THE REL512 IS ENERGIZED. 7. Draw out the inner boards to the extent necessary to make the connections. 8. Make the relay to computer connection per Figure Reinsert the inner boards to their installed position. 10. Energize the relay and check the power LED on the main board to assure it is lit. The LED s on the UI module will not illuminate when programming the main board. 11. Go to the directory C:\REL512\CONFIG\(MAIN, DNP, or RECLOSER). The select the version you are programming. Examples: For MAIN board go to directory C:\REL512\CONFIG\MAIN\VerXXX. For DNP board go to directory C:\REL512\CONFIG\DNP\VerXXX. For RECLOSER board go to directory C:\REL512\CONFIG\RECLOSER\VerXXX. 12. Highlight the CFG file required for the board you are programming. 13. Left click on that file and drag it over the shortcut to CPROG32W.EXE on your Desktop and release it. This will start the program and begin programming the board. 14. Observe the loading operation. Microprocessor will be reset and the 32P file will be loaded. This will be done twice. Then the srecord will be loaded, the FLASH will be erased, then it will be Programmed and then verified. If this process was successful the CPROG32W program will terminate. If there was an error the CPROG32W.EXE program WILL NOT TERMINATE and will display the point where the error occurred. If any error occurs recheck all connections and repeat this step. 15. When the new firmware is loaded, de-energize the relay and remove the connection. 16. Replace the front panel making sure to connect the LCD cable. 17. Check to make sure that the LED RESET button is not stuck behind the cover panel. To do this push with just enough force to slightly bend the front cover and see that the LED RESET button protrudes through the cover and you can feel the button depress when pressing it.. Do not push the cover to hard in case the button is stuck behind the cover as this may damage the push button. 6

214 REL 512 Firmware Upgrade 18. Following the procedure to restore default settings when energizing the relay. Observe firmware version number during the boot process. The relay should boot correctly with default settings. 19. Once the relay has booted check menu item #1, Product Information, to insure the correct firmware has been loaded. Also note the Settings Database Version number. If it is the greater than the previous version (Number noted in step 4) then the setting saved in step 2 will need to be updated before they can be loaded back to the Relay. If you have the latest version of RELTOOLS that supports this Settings Database Version then open RelWise and from the File Menu and select Open and Update Settings Version then select the Settings Database version to update to. Select the file to update, open it and make note of any changes that RelWise notifies you of. From the File Menu select Save as Bin and save the file. It is recommended that you save the original file by giving the new file some other name. If it is the same as the previous version (Number noted in step 4) then download the Settings saved in step 2 back to the Relay. 20. If you wish, run the acceptance test in the I.B. to verify relay operation with the new firmware. 7

215 ABB Application Note Substation Automation and Protection Division REL 512 AN-40L-99 Overreaching of the Impedance Characteristic Using Automated Testing Introduction A common function of the automated test set is the development of the impedance reach characteristic defined in the impedance plane. The relay reach characteristic is tested with the applied test quantities of V T and I T. One method is to set the phase angle of the applied test current, I T, at a specified value referenced to the test voltage, V T. I T magnitude is increased, from some small value that would have the impedance outside of the operating region, until relay operation occurs. V T and I T are recorded and the impedance, Z T, is computed and compared to the expected results based on the relay settings and operating characteristics. This process is repeated for different angles of I T until the characteristic is adequately defined. Figure 1 is an illustration of how the characteristic is determined for impedances presented to the relay from 0 0 to Figure 1 - Testing the Impedance Characteristic The test results for an adequately designed impedance element will fall on or be very near the predicted curve. When testing the zone-1 impedance units of the REL 512, overreach errors as shown in Figure 2 have be observed while testing with a number of different manufacturers test sets. This application note will show the error is the result of an instantaneous change of current that occurs in the automated test process and recommend testing solutions. Figure 2 - Apparent Impedance Characteristic Error Due To Pulse Testing

216 Impedance Characteristic Testing AN-40L-99 Mho-circle Error The previous generation microprocessor relay such as the REL 301/2, for example, operates using Fourier transform methods using sampled data collected only after the fault inception transient. This is adequate for 1.5 to 2 cycle relay operations. In order to achieve high speed or sub-cycle operation, the REL 512 operates based on computed torque produced by sampled data that includes the fault transient. The response of the REL 512 to this fault inception transient is accurate when operating on the power system where current (and voltage) transient responses are a function of system inductance, capacitance and resistance. Extensive Model Power System testing and accurate EMTP digital system simulation models have verified this. Test set pre-fault to fault state switching transients which are step changes in current are not representative of real system operations. These switching transients can adversely affect the mho-impedance circle characteristic test results. The units can overreach the expected impedance test values for step-changed (pulsed) test currents applied well off the maximum torque angle usually at high values of test current. The result is an undesired momentary operation lasting less than 1/4 cycle after test current application. Because of the momentary nature only zone-1 tripping is affected. Additional discussion is provided under State Switching Analysis. Solutions The REL 512 has fault-transient logic that blocks operation during the first 3/8 cycle after fault inception. Fault inception is defined by a change in both current and voltage. This would prevent relay tripping even if under some remote circumstance a zone-1 impedance unit momentarily operated. Accurate results can be obtained if during the off or prefault state normal voltages and currents are applied, and during the pulse or fault state both voltage and currents are switched to the fault quantities. Accurate impedance characteristic test results can also be obtained using a number of other methods. The first is by ramping the current up in small increments while maintaining constant test voltages. The small changes in current will not affect the impedance unit operation. This requires disabling the zones not being tested. A second alternate method is to use the pulse method with a constant voltage and use a combination of modified mho characteristic tests, complemented with dynamic testing. Testing the forward looking zone impedance characteristics is limited to the line angle (MTA) setting +/ (15 0 to for an MTA of 75 0 ). This provides accurate characteristics in the forward region where relay operations are minimally affected by the pulse transient. These test are complemented with one or more reverse fault dynamic tests which switch from normal operating voltage and current quantities to fault quantities. A third method is to map (program) the Z1 TRIP signal to a programmable output. The mapping logic requires time and delays operation of the ZONE 1 TRIP through the mapped contact by approximately a quarter of a cycle. Using this method the full circle can be tested. State Switching Analysis This analysis is provided to show the effect of current change during state switching. Figure 3 shows the results of two cases. Both cases are identical except for the transient time constant, tc, used when switching from the prefault to fault state. The applied test voltages and currents are shown in Table 1. 2

217 Impedance Characteristic Testing AN-40L-99 Table 1 - Transient Current State Switching Tests State Pre-fault AB Fault Post Fault Quantity Ampl Phas e Ampl Phas e Ampl Phas e Va Vb Vc Ia Ib Ic Time 20 Cycles 5 Cycles 60 Cycles Figure 3 - Tests Using Time Constants of tc = 0.0 and tc = 0.25 Cycle The test quantities represent the test set quantities being applied for a test pulse while determining the impedance characteristics. The voltages are constant for prefault and fault states while the current switches from zero to the test value. For these cases the applied phase A test current leads phase A voltage by 80 0 and leads the phase AB fault voltage by This puts the fault impedance in the fourth quadrant of the of the impedance plot at As illustrated in Figure 2 of the paper, this is the region that is most susceptible to the undesired test operation. Figure 3 shows the results of both tests. The upper window shows the analog quantities. The test with tc = 0, which represents the test set, shows the abrupt transient current between states while the test with tc = 0.25 cycle shows a real world transient current with moderate dc offset. The lower window shows the pertinent measuring unit and logic responses to the two faults. Digital operations for case tc = 0 are shown in black on the light gray line. Digital operations for the case tc = 0.25 cycle are shown below the gray line, Both digital operations are apparent for the signal FAULT IN DETECTOR I. For case tc = 0, the zone-1 phase-to-phase unit, Z1 Phase, momentarily operated. This short operation resulted in the relay tripping as indicated by the logic signals Z1 TRIP and DSP TRIP SEAL. It is also noted that the forward pilot zone and supervising logic, PFT, momentarily operated as well. Correct operations shown for case tc = 0 are FAULT IN DETECTOR I and PRT, the reverse pilot zone and supervising logic. For the case tc = 0.25, there were no incorrect operations. The second, and lower, digital operation lines show operations for this case. The signals PRT and FAULT IN DETECTOR I operated for both cases. 3

218 Impedance Characteristic Testing AN-40L-99 Case tc = 0 was modified to demonstrate relay operation when there is a voltage change at fault inception. The test quantities in Table 2 were used. A time constant of zero was used. Table 2 - Transient Current and Voltage State Switching Tests State Pre-fault AB Fault Post Fault Quantity Ampl Phas e Ampl Phas e Ampl Phas e Va Vb Vc Ia Ib Ic Time 20 Cycles 5 Cycles 60 Cycles The test results shown in Figure 4 show the momentary operation of the Z1 Phase unit as expected for tc = 0. Also shown operated are the signals FAULT IN DETECTOR V and FLT TRANS BLOCK. No Tripping occurs. The signal FLT TRANS BLOCK is asserted at fault inception with the operation of both FAULT IN DETECTOR V and FAULT IN DETECTOR I and blocks tripping for 0.4 cycle. Figure 4 - Test Showing Trip Blocking for Current Time Constant tc = 0 The above tests demonstrate the adverse effect of test set current switching on high-speed relays. The tests also show that including a very small transient time constant (0.25 cycle) effectively eliminated the incorrect momentary operation of the impedance units. Further, trip blocking is effective in blocking this transient condition to allow dynamic testing. Contributed by: Elmo Price Revision 0, 08/18/99 4 ABB, Inc Snowdrift Road Allentown, PA Fax powerful.ideas@us.abb.com Web:

219 ABB Application Note REL 512 AN-41L-99 Substation Automation and Protection Division Fault Location and Phase Selection from the Digital Fault Recording Introduction One of the primary features of the REL 512 is the digital fault recording function. It collects fault or event data based on relay settings and very sensitive and accurate voltage and current change detectors. It captures a 16-cycle snapshot that includes fault inception, fault clearing (tripping) and any evolving fault event that should occur in between. This is referred to as a single record event if fault clearing occurs within 14 cycles of the fault inception. This normally includes zone-1 and pilot tripping and can be expected for 100% of faults on the protected line for a pilot system and 90% of the faults for a non-pilot system where the zone-1 reach is 90% of the protected line length. Should the time between fault inception and fault clearing be greater than 14 cycles then two records are captured, 16 cycles of fault inception and 16 cycles of fault clearing. Time-delayed tripping such as a zone-2 trip would be an example of a two-record event. The following discusses the operation of the REL 512 digital fault recording function, how the DFR records are used to compute fault location and phase selection, related settings and expected test results. Pre- and Post-fault (initiation) Data Requirements Pre-Initiation Data Correct fault location and faulted phase selection requires the use of prefault phasor quantities computed from a one cycle [period] of captured sampled data. It is necessary that the prefault samples have correct phase alignment with the fault cycle [period] of sampled data used in the calculation. The fault cycle used could be any cycle during the fault. The REL 512 uses the second fault cycle as a compromise between the fault inception and high-speed clearing transients. Figure 1 - Prefault and Fault Cycle Phase Alignment Correct phase alignment requires that the two sample sets, prefault and fault, are taken from the same time points in their respective cycles. This is shown in Figure 1. If you were to start counting from one with the first prefault cycle sample up to and not including the first selected fault cycle sample and divide that number by the sample rate (samples/cycle), in this case 20, the remainder must be zero.

220 Fault Location and Phase Selection from the Digital Fault Recording AN-41L-99 Post Initiation Data It is desired to capture the fault for its full duration from inception through clearing and reclosing. Forty-five cycles is recommended for conventional DFR applications. For protective relays this is not always practical to do with one continuous record. Correct zone-1 tripping for microprocessor relays would be expected to be in the two to three cycles. This is typically followed by two to four cycles of breaker clearing. Therefore, a 7- cycle post-initiation data record is adequate for most zone-1 or other three cycles or less tripping function. One level greater would be to capture data for sequential tripping on the protected line. Sequential tripping is when a remote terminal clears a line end fault removing the end-feed and the local end responds to the system voltage and current changes (decrease of apparent impedance) and trips. An example would be a loss-of-load trip function where the remote end trips and the local end responds after remote breaker clearing. Considering that the trip logic and breaker trip will be sequential (one after the other) for the line terminal relays, 14 cycles of post-initiation data is collected by the REL 512. For a zone-2 fault a record with pre- and post-initiation data can be recorded for the fault inception. The change detector drops out during the steady state fault, but will operate again for tripping or the breaker clearing at the end of zone-2 time. These will initiate a second record for this event. There is no real need for the interim steady state fault data between the two records except possibly as a means for maintaining time coordination. The REL 512 will time-tag the two records with less than 1.0 ms resolution providing excellent coordination for the two records. Recording the Fault Record The following is a scenario for a typical fault recording in the REL 512. Once the voltage and current change detection logic (FAULT INCEPTION DETECTOR logic signal) indicating a fault inception or system disturbance has asserted the two preceding cycles of prefault [initiation] data is captured and the post fault data for the next 14 cycles is collected. The fault impedance is calculated at each post-fault sample during the 14 cycles, and if determined to be within the reach of the forward or reverse pilot zones, the 16 (2 preand 14 post-fault [initiation]) cycle record is time-tagged and saved. Change detection is not required while recording, but after the 14 cycles (the end of the record) the change detector is monitored again. If there are no changes the fault has cleared the event is over. A typical single record event is shown in Figure 2. Figure 2 - Typical Single Record Event 2

221 Fault Location and Phase Selection from the Digital Fault Recording AN-41L-99 If the faults still persist, such as a zone-2 fault, the change detector will not operate until fault clearing [or other interim disturbance]. At that time a second record for the zone-2 event is saved and time-tagged. A typical two-record event is illustrated in Figure 3. Both records are time-tagged and can be coordinated within 1.0 ms. Figure 3 - Typical Two Record Event Faulted Phase Selection and Fault Location The saved fault records are used to compute the fault location and faulted phase selection which is displayed on the relay s front panel LCD user interface (UI) and LED s. Only records that include the fault inception can be used to compute accurate results. This requires distinguishing between fault inception and fault clearing records for the time-delayed trips with two record events. Fault inception records contain the true prefault and fault currents that are necessary for accurate computation. Fault clearing or tripping records contain fault and fault clearing currents that will produce erroneous fault location and phase selection results. The REL 512 avoids using the fault clearing records to provide the information displayed on the relay s front panel. In some very remote cases, however, it is unavoidable and erroneous information is displayed. Fortunately this only occurs during testing or possibly tripping for zone-3 or backup overcurrent trips for faults not on the protected line. The following provides information that is useful when applying or testing the DFR function. Settings The DATA CAPTURE setting defines what fault records are recorded and how the relay s front panel LED s are illuminated for faulted phase selection. The settings are DVDI, PILOT, and TRIP. The DVDI setting captures all events triggered by the change detector logic signal FAULT INCEPTION DETECTOR. It operates for fault inceptions, fault clearing and evolving faults that are within the range of the change detector s sensitivity. A 7.0 volt change of any voltage and a 0.5 amp change of any current are required to assert FAULT INCEPTION DETECTOR which triggers and captures a record for this setting. This setting allows the recording of events very remote to the protected line. This can result in recording many undesired events that can rapidly fill the memory pushing out valuable data. It is recommended to 3

222 Fault Location and Phase Selection from the Digital Fault Recording AN-41L-99 retrieve this data often to avoid data loss. Further, records for faults remote to the protected line will produce unreliable fault location and phase selection results due to other current feeding the fault from sources other than the relay location. This setting is only recommended for troubleshooting. The PILOT setting requires that one of the forward or reverse pilot impedance units operate to capture a record. This restricts the area of fault data capture and meaningful fault location to the vicinity of the protected line. If a zone-1 or pilot trip occurs within 14 cycles after the fault inception then only one record is necessary to capture the event and display fault location data. If a time delayed trip occurs after the 14-cycle period, such as a non-pilot zone-2, then a second record of fault clearing is recorded. If the zone-2 fault is cleared by the remote protection and tripping does not occur, then one or two records of fault data are still recorded and fault location and phase selection computed and the information is displayed in the UI and LED s. The TRIP setting allows capturing fault records and displays fault data the same as the PILOT setting except the LED s are not illuminated unless a trip occurs. However, records are saved and the UI is updated. Operation The logic signal FAULT INCEPTION DETECTOR is asserted when the voltage and current change as defined above. This signal will assert for fault inceptions, evolving faults and breaker clearing transients. It is not asserted during normal operating and steady state fault conditions. If this signal is immediately followed by the operation of any forward or reverse pilot impedance unit, then the record is saved and is recognized as fault inception data from which accurate fault location and phase selection can be computed and the LED s and UI updated. The fault data is also shown in downloadable fault record header information that is available from the computer terminal emulation interface. If any forward or reverse pilot unit is already operated when the FAULT INCEPTION DETECTOR signal is asserted, then the record is saved and is recognized as fault clearing data and is not used to compute the fault location and phase selection. In this case the fault location and phase selection results from the previous fault inception case are used for the LED, UI and fault record header information. Application and Testing As previously stated, faults remote to the protected line will produce unreliable fault location and phase selection results due to other current feeding the fault from sources other than the relay location. Therefore, accurate fault location and faulted phase selection can only be expected for faults on the protected line. The REL 512 limits the region of fault location coverage to the forward and reverse pilot zones with the DATA CAPTURE settings of PILOT or TRIP. This allows accurate fault information for any high-speed or timedelayed trips on the protected line. Generally, tripping of the relay is not expected for faults on adjacent lines unless there is a failure of the adjacent line s primary protection. If time-delayed tripping occurs for a fault outside the pilot region or if there is significant infeed to the fault location, then the fault information displayed on the LED s and UI will be unreliable. This should be considered when testing. When testing with conventional test sets there are no infeed conditions to consider. However, the set reach of the forward pilot phase and ground impedance units will affect fault location and faulted phase selection results. Any test that does not operate any of the pilot impedance units is subject to error. It is, therefore, recommended to set the forward pilot phase and ground unit reaches to operate for all operating unit (zone- 2, zone-3, backup overcurrent, etc.) tests where accurate fault location or faulted phase selection is desired. 4

223 Fault Location and Phase Selection from the Digital Fault Recording AN-41L-99 Fault Records Following is an example list of downloadable fault records that are accessed via the computer terminal emulation interface. The records were captured for a number of zone-1, zone-2 and zone-3 operations. They are accessed from the root menu s Retrieve Data menu option. [1] Receive Fault Records from Relay [2] Receive Settings from Relay Fault Records [A] Record 0 Fri Sep :25: Typ:A-B-C Loc: 3.40 Km [B] Record -1 Fri Sep :24: Typ:A-B-C Loc: 4.40 Km [C] Record -2 Fri Sep :24: Typ:A-B-C Loc: 4.40 Km [D] Record -3 Fri Sep :14: Typ:C-G Loc: 2.63 Km [E] Record -4 Fri Sep :24: Typ:C-G Loc: 2.62 Km [F] Record -5 Fri Sep :44: Typ:C-G Loc: 2.61 Km [G] Record -6 Fri Sep :24: Typ:C-G Loc: 2.63 Km [H] Record -7 Fri Sep :56: Typ:C-G Loc: 2.63 Km [I] Record -8 Fri Sep :23: Typ:C-G Loc: 2.63 Km [J] Record -9 Fri Aug :28: Typ:B-G Loc: 2.62 Km [K] Record -10 Fri Aug :20: Typ:A-G Loc: 6.15 Km [L] Record -11 Fri Aug :20: Typ:A-G Loc: 6.15 Km [M] Record -12 Fri Aug :17: Typ:C-G Loc: 2.64 Km [N] Record -13 Fri Jul :17: Typ:B-G Loc: 4.57 Km [O] Record -14 Fri Jul :17: Typ:B-G Loc: 4.57 Km Enter selection: The impedance settings are zone-1 = 4.0, zone-2 = 6.0, zone-3 = 9.0 and the forward pilot zone =12.0. The zone-2 timers are set to 0.5 seconds and the zone-3 timers are set to 2.0 seconds. The fault distance parameters are set such that one ohm fault impedance is equal to one kilometer of fault distance. Records A, D, E, F, G, H, I, J and M are all single record events of varying fault types and are within zone-1. Records B and C comprise a two record event capturing a zone-2 time delay trip. Record C is the fault inception and record B is the fault clearing second later. Records K and L comprise a two record event capturing a zone-3 time delay trip. Record L is the fault inception and record K is the fault clearing 2.2 seconds later. Records N and O are another two record event for a zone-2 time-delayed trip. The LED and UI information are also part of the fault record. For a single record event the LED and UI information in the fault record will be as was displayed at the end of the event. For a two record event the LED and UI information in the fault clearing record will be as was displayed on the relay at the end of the event. This is the correct information. The LED and UI information in the fault inception record will be as was displayed on the relay at the start of the event if the DATA CAPTURE setting is set to TRIP. If the LED s and UI have been reset (cleared) then the information will be null as expected. Remember, this record was captured, processed and saved before the end of the event (no tripping has occurred) and the decision to illuminate the LED s has not been made yet. If the LED s and UI have not been reset then the information in the record will be the same as that displayed on the relay at the start of the fault. This may lead to confusion when analyzing the fault record, therefore, resetting the LED s after the fault is reviewed is always a good practice in both application and testing. Contributed by: Elmo Price Revision 0, 09/15/99 5

224 Fault Location and Phase Selection from the Digital Fault Recording AN-41L-99 ABB, Inc Snowdrift Road Allentown, PA Fax Web: 6

225 ABB Application Note REL 512 AN-54L-00 Substation Automation and Protection Division Retrieving REL 512 Data Using Windows HyperTerminal Introduction The REL 512 is provided with an ASCII communications interface for simple access to settings and digital fault record data. Access to the data can be made with almost any Windows based terminal emulation software on almost any microcomputer using programs such as Windows HyperTerminal, CrossTalk or Procom Plus. There is such a wide variety of communication programs available that it is virtually impossible to provide specific instructions for each on. Therefore, this application note will be limited to retrieving data from the REL 512 using Windows HyperTerminal, a program provided on computers with Windows 95, 98 and NT operating systems. The REL 512 Terminal Emulation Protocol Setting The relay is delivered with the following communication settings for both the front and rear interfaces: Bit rate 9600 Word Length 8 Parity None Stop Bits 2 Except for the bit rate, these are the recommended communication settings. The bit rate can be set up to 115,200 bits/second. The highest rate supported by your computer is recommended. Interactive dialog with the relay is achieved when the relay and communications program agree. Also, transferring data files between the relay and computer is done using the Xmodem (Checksum or CRC) binary file transfer protocol. The following settings are typical for communication programs. They may vary depending on specific communications program and computer requirements. Terminal Emulation DEC VT-100 or VT-102 (ANSI) Binary Transfers Xmodem (Checksum or CRC) Terminal Preferences Function, Arrow, and Ctrl Keys should be set to OFF Baud Rate 9600 (based on modem and relay setting) Data Bits 8 (relay setting) Stop Bits 2 (relay setting) Parity None (relay setting) Flow Control None (or No Flow Control) Comm Port Computer s communication port (often Comm 1). Both the correct settings and communications cable are required to allow the communication link between computer and relay to be made. The correct cable for connection to the relay s front port is a standard PC to Modem cable (9-pin D connectors, male to female, pin to pin connections). If connecting to the rear port with the same cable, it is necessary to use a null-modem and a male-to-female adapter.

226 Retrieving Data with Windows HyperTerminal AN-54L-00 Connecting with HyperTerminal The following procedure sets up a HyperTerminal 9600 bits/second communications file that can be used to communicate with the REL 512 also set at 9600 bits/second. From Windows 95, 98 or NT Start menu select Programs, Accessories and HyperTerminal. The following Connection Description dialog box appears. Enter the file name to which you want to save the connection settings. Press OK. The Connect To dialog box appears. Enter the appropriate computer s modem and phone number connection data if accessing remotely. For local direct access select the computer s communication port. This is typically COM1. Press OK. This will bring up the COM# Properties dialog box. Enter the values set in the REL 512. Press OK. 2

227 Fault Location and Phase Selection AN-54L-00 This will bring up Hyper Terminal s text dialog screen. Press <ENTER> or < / > and the REL 512 Root Menu will appear if the proper connection is made. If the Root Menu does not appear, then communications is not achieved. In this case check your cable connection, COM# and Hyper Terminal s COM# Properties. The current COM# Properties is available via the File, Properties menu. Retrieving REL 512 Data From the REL 512 Root Menu select [7] Retrieve Data. Press < ENTER > and the Retrieve Data menu appears. You can download the recorded digital fault records or the relay s settings. Retrieve Data [1] Receive Fault Records from Relay [2] Receive Settings from Relay Selection => 1 Select [1] to receive fault records. Up to 15 fault records may be available. They are listed on this screen in order of occurrence by time and date, the most recent being [A] and up to [O] being the oldest. Fault Records [A] Record 0 Mon Feb :26: Typ:A-G Loc: 3.06 Km [B] Record -1 Mon Feb :24: Typ:A-G Loc: 3.08 Km [C] Record -2 Mon Feb :24: Typ:A-G Loc: 3.08 Km [D] Record -3 Mon Feb :04: Typ:A-B-C Loc: 2.00 Km Enter selection: A Select the desired record and the following message appears: Transmit Capture Data to Host Terminal Ready to send 16 cycles (40320 bytes, 319 blocks) of captured data to host terminal via XMODEM Press ESC to exit, any other key to continue with transmission. Note: The above message will read Transmit Settings Data to Host Terminal if you selected [2] Receive Settings from Relay 3

228 Retrieving Data with Windows HyperTerminal AN-54L-00 Press < ESC > to abort or any other key to continue. Press the space bar and the message to start transfer appears. Start host terminal XMODEM receive protocol now. Select Receive File from the Transfer Menu to setup for receiving the data file. The Receive File dialog box appears. Use the Browse button to locate the folder(directory) where the file is to be received. Set the receiving protocol to Xmodem. Press < Receive > The Receive Filename dialog box appears. Type the filename you want the downloaded fault record copied to. Be sure to add the.rel file extension for fault data (or.bin for settings). The download process is monitored. You will observe the Packets to increase from 0 to 320 in the transfer process. Timeout may occur if you were slow in setting up the receive file parameters. If it does, cancel the transfer and restart the process. The following message appears upon a successful completion of the file transfer: SUCCESS - Transmission complete You can now open this file in the RELWAVE Fault Analysis Program. Contributed By: Elmo Price 02/14/00 4 ABB, Inc Snowdrift Road Allentown, PA Fax powerful.ideas@us.abb.com Web: