Page 1 Digital Energy Plus Line Distance Protection System Instruction Manual Product version: 1.9x GE publication code: 1601-9019-F3 (GEK-113468C) 1601-9019-F3...
Page 2 The contents of this manual are the property of GE Multilin Inc. This documentation is furnished on license and may not be reproduced in whole or in part without the permission of GE Multilin. The content of this manual is for informational use only and is subject to change without notice.
Page 3: Table Of Contents
Plus Line Distance Protection System Table of contents 1 INTRODUCTION Safety symbols and definitions..................1 For further assistance ....................1 2 PRODUCT Product description......................3 DESCRIPTION Firmware architecture ..........................4 Hardware architecture ..........................5 Communications overview ........................8 Front panel interface ............................8 Protection features............................. 10 Automation features..........................
Page 4 TABLE OF CONTENTS Dielectric strength ............................43 Main processor module ..........................44 Communications module.........................46 Power supply module..........................46 AC modules..............................47 Contact input and output modules .....................49 Inter-relay communication modules....................53 Install software ......................59 System requirements..........................59 Install software..............................60 Connect for first time with Quick Connect ..................62 Plus Configure the D90 for software access ..................63...
Page 5 TABLE OF CONTENTS PRP actual values ............................. 104 Date and time actual values and commands ................104 Modbus communications..................105 Modbus protocol............................106 Modbus user map ............................ 106 DNP communications ....................107 DNP protocol............................... 107 DNP user point list............................ 111 IEC 60870-5-104 communications .................
Page 6 TABLE OF CONTENTS Distance elements............................187 Current elements ............................229 Voltage elements ............................265 Breaker failure ............................276 Wattmetric zero-sequence directional ground fault ...............287 Control elements ....................... 291 Pilot-aided schemes ..........................292 Setting group control ..........................323 Trip output..............................324 FlexMatrix ..............................330 VT fuse failure .............................333 Open pole detector ..........................335 Autoreclose..............................338 Underfrequency............................361 Overfrequency............................363...
Page 7 TABLE OF CONTENTS Automation virtual outputs........................463 Contact input and output default assignment................464 Contact input configuration ........................ 465 Contact outputs ............................469 Virtual analog outputs ........................... 471 Using shared operands in automation ..................471 Automation logic ....................... 473 Automation operators..........................476 Automation logic equation editor.....................
Page 8 TABLE OF CONTENTS Data logger channel configuration ....................558 Metered values ......................560 Phase current metering .........................564 Ground current metering ........................566 Phase voltage metering.........................566 Auxiliary voltage metering........................567 Power metering ............................568 Energy metering ............................569 Frequency metering ..........................570 Tracking frequency ..........................570 Clearing metered values........................571 Observing current and voltage phasors ...............
Page 9 TABLE OF CONTENTS Distance element time domain algorithm..................628 Distance element frequency domain algorithm................ 628 Distance supervision..........................629 Distance characteristics........................630 Memory polarization..........................636 Distance elements analysis......................... 637 Phase distance applied to power transformers ..........642 Example of system with power transformers................645 Ground directional overcurrent theory..............
Page 10 TABLE OF CONTENTS PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 11: Introduction
Indicates practices not related to personal injury. FASTPATH: For further assistance For product support, contact the information and call center as follows: GE Digital Energy 650 Markland Street Markham, Ontario Canada L6C 0M1 Worldwide telephone: +1 905 927 7070...
Page 12 FOR FURTHER ASSISTANCE CHAPTER 1: INTRODUCTION Worldwide e-mail: [email protected] Europe e-mail: [email protected] Website: http://gedigitalenergy.com/multilin PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 13: Product Product Description
Plus Line Distance Protection System Chapter 2: Product description Product description This chapter outlines the product, order codes, and specifications. Product description Plus Designed for superior performance and ease-of-use, the D90 is a single platform solution for protecting transmission lines from medium voltage (MV) to extra high voltage (EHV) and cables of various voltage levels.
Page 14: Firmware Architecture
PRODUCT DESCRIPTION CHAPTER 2: PRODUCT DESCRIPTION Firmware architecture Plus The D90 is a sub-cycle distance protection and advanced automation controller that is organized into six functions. • Protection • Automation • Metering • Digital fault recorder (DFR) • Equipment manager •...
Page 15: Hardware Architecture
CHAPTER 2: PRODUCT DESCRIPTION PRODUCT DESCRIPTION Figure 1: Functional architecture Plus The D90 also includes shared operand functionality. Output signals from the various functions can be assigned as shared operands available to all functions. These signals can then be assigned as inputs within other functions. For example, assume that the protection FlexLogic operand is required as a PHASE TOC1 OP...
Page 16 PRODUCT DESCRIPTION CHAPTER 2: PRODUCT DESCRIPTION The AC module measures AC currents and voltages derived from CTs and VTs. These signals are sampled and digitized and sent over the device’s bus to the CPU module for further processing. A version is available that accepts nominal 5 A current and another that accepts nominal 1 A current.
Page 17 CHAPTER 2: PRODUCT DESCRIPTION PRODUCT DESCRIPTION Plus Figure 2: D90 block diagram Plus Figure 3: D90 hardware overview Plus An option of the D90 is support for the Parallel Redundancy Protocol (PRP) of IEC 62439- 3 (clause 4, 2012). The PRP allows high availability in substation automation networks. It applies to networks based on Ethernet technology (ISO/IEC 8802-3).
Page 18: Communications Overview
To communicate through the D90 rear RS485 port from a computer’s RS232 port, the GE Multilin RS232/RS485 converter box is required. This device (catalog number F485) connects to the computer using a straight-through serial cable. A shielded twisted-pair (20, Plus 22, or 24 AWG) connects the F485 converter to the D90 rear communications port.
Page 19 CHAPTER 2: PRODUCT DESCRIPTION PRODUCT DESCRIPTION of metered values, such as voltage, current, demand, energy, and sequence components, to a comprehensive display of fault reports, sequence of events, and transient recorded waveforms. The front panel interface also displays device health information with critical and non-critical alarm status.
Page 20: Protection Features
PRODUCT DESCRIPTION CHAPTER 2: PRODUCT DESCRIPTION Figure 7: Front panel USB connection Protection features Plus The D90 is designed for superior performance and ease-of-use, providing a single platform solution for protecting transmission lines from medium voltage (MV) to extra high voltage (EHV) and cables of various voltage levels.
Page 21 CHAPTER 2: PRODUCT DESCRIPTION PRODUCT DESCRIPTION Distance elements on page 1 Application to series-compensated lines Plus The D90 provides enhanced stability and security by employing an adaptive distance reach control to cope with the overreaching and sub-synchronous oscillations when applied to, or in the vicinity of, series compensated lines. For directional integrity, the relay uses memory voltage polarization, and a multi-input comparator is used to deal with current inversion issues in series compensated lines.
Page 22 PRODUCT DESCRIPTION CHAPTER 2: PRODUCT DESCRIPTION Communication aided (pilot) schemes Plus The D90 supports different pilot scheme functions for fast fault clearance for any faults within the protected line. The following types of pilot-aided schemes are available: • Direct under-reaching transfer trip (DUTT) •...
Page 23 CHAPTER 2: PRODUCT DESCRIPTION PRODUCT DESCRIPTION Overfrequency and underfrequency protection The multiple stages of underfrequency and overfrequency elements can be used to initiate load shedding or remedial action schemes or frequency-based load restoration schemes during lack of generation in the network or due to sudden load drops. When combined Plus with the advanced automation capabilities of the D90 , flexible special protection...
Page 24: Automation Features
PRODUCT DESCRIPTION CHAPTER 2: PRODUCT DESCRIPTION Figure 9: Breaker-and-a-half configuration example Single-pole tripping Plus The D90 relay uses an advanced phase selection algorithm that provides fast and accurate fault type identification even under weak-infeed conditions. The pilot schemes for single pole tripping offer an option to send the permissive/blocking signal using one, two or four bits of information.
Page 25: Equipment Manager Features
CHAPTER 2: PRODUCT DESCRIPTION PRODUCT DESCRIPTION For additional information, refer to: Synchrocheck on page 450 Scalable hardware Plus The D90 is available with a multitude of input and output configurations to suit the most demanding application needs. The expandable modular design allows for easy configuration and future upgrades.
Page 26: Digital Fault Recorder Features
PRODUCT DESCRIPTION CHAPTER 2: PRODUCT DESCRIPTION • Voltage symmetrical components • Current phasors • Current symmetrical components • Current true one-cycle RMS values • Active, reactive, and apparent power • Power factor (all power values per phase and total) • Four-quadrant energy •...
Page 27: Communications Features
CHAPTER 2: PRODUCT DESCRIPTION PRODUCT DESCRIPTION Figure 12: Typical front panel fault report display Sequence of events recorder Plus The D90 contains an advanced sequence of events recorder with the capability to record up to 8,000 events. Event information can be accessed either through the front panel or the EnerVista Launchpad software.
Page 28: Order Codes
ORDER CODES CHAPTER 2: PRODUCT DESCRIPTION Order codes The order code indicates the product options applicable. Plus The D90 is available as a 19-inch horizontal rack-mount unit. It consists of a number of required and optional modules. Module options are specified at the time of ordering. The order codes shown are subject to change without notice.
Page 29 Dropout level:............>102% of pickup Level accuracy: ............±0.5% of reading from 10 to 208 V Curve shapes:............GE IAV inverse, definite time Curve multiplier: ..........0.00 to 600.00 in steps of 0.01 Timing accuracy: ..........±3% of operate time or ±4 ms (whichever is greater) BREAKER FAILURE Mode:................single-pole, three-pole...
Page 30 SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION FLEXCURVES™ Number: ..............4 (A through D) Reset points:............40 (0 through 1 of pickup) Operate points:............ 80 (1 through 20 of pickup) Time delay: ............0 to 65535 ms in steps of 1 FLEXELEMENTS™ Elements:..............
Page 31 CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS Figure 14: Ground distance operating curves PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 32 SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION GROUND INSTANTANEOUS OVERCURRENT Pickup level:............0.000 to 30.000 pu in steps of 0.001 Dropout level: ............<98% of pickup Level accuracy at 0.1 to 2.0 × CT: ....±0.5% of reading or ±1% of rated (whichever is greater) Level accuracy at >2.0 ×...
Page 33 CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS NEGATIVE-SEQUENCE DIRECTIONAL OVERCURRENT Directionality:............co-existing forward and reverse Polarizing: ...............voltage Polarizing voltage: ..........V_2 Operating current:..........I_2 Level sensing (zero-sequence):.....|I_0| – K × |I_1| Level sensing (negative-sequence): ...|I_2| – K × |I_1| Restraint, K: ............0.000 to 0.500 in steps of 0.001 Characteristic angle: .........0 to 90°...
Page 34 SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION NEUTRAL DIRECTIONAL OVERCURRENT Directionality:............co-existing forward and reverse Polarizing:............... voltage, current, dual Polarizing voltage:..........V_0 or VX Polarizing current: ..........IG Operating current:..........I_0 Level sensing: ............3 × (|I_0| – K × |I_1|), IG; independent for forward and reverse Restraint (K): ............
Page 35 CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS OPEN POLE DETECTOR Functionality: ............detects an open pole condition, monitoring breaker auxiliary contacts, the current in each phase and optional voltages on the line Current pickup level:..........0.000 to 30.000 pu in steps of 0.001 Line capacitive reactances: ......300.0 to 9999.9 secondary ohms in steps of 0.1 Remote current pickup level:......0.000 to 30.000 pu in steps of 0.001 Current dropout level:........pickup + 3%;...
Page 36 SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION Figure 15: Phase distance operating curves PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 37 Pickup level: ............0.000 to 1.100 pu in steps of 0.001 Dropout level:............>102% of pickup Level accuracy: ............±0.5% of reading from 10 to 208 V Curve shapes:............GE IAV Inverse; Definite Time (0.1 second base curve) Curve multiplier: ..........0.00 to 600.00 in steps of 0.01 Timing accuracy for operation at <0.90 ×...
Page 38 SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION POWER SWING DETECT Functions:............... power swing block, out-of-step trip Characteristic:............mho or quadrilateral Measured impedance: ........positive-sequence Blocking and tripping modes:....... two-step or three-step Tripping mode:.............early or delayed Current supervision pickup:......0.050 to 30.000 pu in steps of 0.001 Current supervision dropout: ......
Page 39: Automation Specifications
CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS UNDERFREQUENCY Elements: ..............2 Minimum signal: ..........0.10 to 1.25 pu in steps of 0.01 Pickup level: ............20.00 to 65.00 Hz in steps of 0.01 Dropout level:............pickup level + 0.03 Hz Level accuracy: ............±0.01 Hz Time delay:.............0 to 65.535 seconds in steps of 0.001 Timer accuracy:...........±3% or 4 ms (whichever is greater) VT FUSE FAILURE SUPERVISION Elements: ..............1 per source...
Page 40: Equipment Manager
SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION AUTOMATION VIRTUAL OUTPUTS Output points: ............255 Programmability: ..........output of an automation logic equation or input to an automation logic equation BREAKER CONTROL Mode:................ single-pole, three-pole Control: ..............open/close, local/SCADA Control seal-in:.............0 to 2000 ms in steps of 1 BREAKER INTERLOCKING Interlocking inputs: ..........
Page 41: Metering Specifications
CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS Metering specifications CURRENT METERING Type:................phase and ground RMS current Accuracy at 0.1 to 2.0 × CT:......±0.25% of reading or ±0.1% of rated (whichever is greater) at 50/60 Hz nominal frequency Accuracy at >2.0 × CT:........±1.0% of reading, at 50/60 Hz nominal frequency DATA LOGGER Channels: ..............1 to 16 Parameters:............any FlexAnalog value...
Page 42: Digital Fault Recorder Specifications
SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION Digital fault recorder specifications DISTURBANCE RECORDER Storage capacity:..........one record with all available channels at 60 samples per second for 40 seconds Maximum records: ..........64 Sampling rate:............1 sample per cycle Sampling accuracy:........... <1 ms per second of recording Analog channels: ..........
Page 43: Front Panel Interface
CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS TRANSIENT RECORDER Storage capacity:..........one record with all available channels at 32 samples per cycle for 1 minute Number of records:..........1 to 64 Sampling rate:............16 to 256 samples per power cycle Timestamp accuracy:........<10 μs per second of recording Analog channels: ..........up to twelve 16-bit, unprocessed, AC input channels Analog channel data:........any FlexAnalog quantity Digital channels:..........up to 128...
Page 44: Hardware Specifications
SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION METERING DISPLAY Summary:............... displays present values of voltage, current, real power, reactive power, power factor, and frequency on a per-phase and total basis Phasors: ..............digital and graphical display of present voltage and current magnitudes and angles Sequence components:........
Page 45 CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS CONTACT OUTPUTS: SOLID-STATE RELAY Make and carry for 0.2 s:.........30 A as per ANSI C37.90 Continuous carry: ..........6 A Break at L/R of 40 ms:........10 A at 250 V DC Operate time:............<100 μs Contact material: ..........silver alloy CONTROL POWER EXTERNAL OUTPUT Capacity: ..............100 mA DC at 48 V DC Isolation:..............2 kV...
Page 46: Communications Specifications
SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION RS485 PORT Baud rates: ............300, 600, 1200, 2400, 4800, 9600, 19200, 38400, 57600, 115200 Protocol:..............Modbus RTU and DNP 3.0 Distance:..............1200 m Isolation: ..............2 kV SOLID-STATE RELAY Make and carry for 0.2 s: ........30 A as per ANSI C37.90 Carry continuous: ..........
Page 47: Inter-Relay Communications Specifications
CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS TELEPROTECTION Input points:............16 per channel Remote devices: ..........3 Default states on loss of communications:...........On, Off, Latest/On, Latest/Off Ring configuration: ..........No Data rate:..............64 or 128 kbps CRC: ................32-bit PARALLEL REDUNDANCY PROTOCOL (PRP) (IEC 62439-3 CLAUSE 4, 2012) Ports used: .............2 and 3 Networks used: ............10/100 MB Ethernet Inter-relay communications specifications...
Page 48: Environmental Specifications
SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION TYPE TESTS Vibration: ..............IEC 60255-21-1, 1G (class Bm) Shock / bump: ............IEC 60255-21-2, 10G (class Bm) Seismic (single axis): .......... IEC60255-21-3, 1G / 3.5 mm (class 1) Make and carry (30 A):........IEEE C37.90 Conducted immunity:........
Page 49: Installation
The Instruction Manual outlines how to install, configure, and use the unit. The Communications Guide is for advanced use with communications protocols. The warranty is included at the end of this instruction manual and on the GE Digital Energy website. PLUS...
Page 50: Panel Cutouts
PANEL CUTOUTS CHAPTER 3: INSTALLATION Panel cutouts Plus The D90 is available as a 19-inch rack horizontal mount unit. The modular design allows the relay to be easily upgraded and repaired by qualified service personnel. The faceplate is hinged to allow access to the removable modules. To minimize risk of electrical shock from contact with the power terminals, install the IMPORTANT: unit in an electrical closet/enclosure whereby the terminal connections are not readily...
Page 51: Rear Terminal Layout
CHAPTER 3: INSTALLATION PANEL CUTOUTS Figure 17: Panel cutout dimensions Rear terminal layout Plus Terminal number assignments in the D90 are represented by three characters, assigned in order by module slot position, row number, and column letter. The figure provides an example of rear terminal assignments. Figure 18: Rear terminal view Slot A houses the power supply module.
Page 52: Wiring
WIRING CHAPTER 3: INSTALLATION Wiring Typical wiring Plus The figure provides an example of how to wire the D90 . Actual wiring varies with application. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 53: Dielectric Strength
CHAPTER 3: INSTALLATION WIRING Figure 19: Typical wiring diagram Dielectric strength Dielectric strength is the maximum electric strength that can be sustained without breakdown. It is measured in volts. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 54: Main Processor Module
WIRING CHAPTER 3: INSTALLATION Plus The table shows the dielectric strength of the UR -series module hardware. Plus Table 1: Dielectric strength for UR -series hardware Function Terminals Dielectric strength from Power supply module high (+), low (+), (–) chassis 2000 V AC for 1 minute Power supply module 48 V DC (+) and (–)
Page 55 CHAPTER 3: INSTALLATION WIRING To minimize errors from noise, the use of shielded twisted-pair wire is recommended. Correct polarity must also be observed. For instance, the relays must be connected with all RS485 “+” terminals connected together, and all RS485 “–” terminals connected together. Though data is transmitted over a two-wire twisted-pair, all RS485 devices require a shared reference, or common voltage.
Page 56: Communications Module
WIRING CHAPTER 3: INSTALLATION IRIG-B port IRIG-B is a standard time code format that allows stamping of events to be synchronized among connected devices. The IRIG-B code allows time accuracies of up to 100 ns. The IRIG time code formats are serial, pulse width-modulated codes that can be either DC level shifted or amplitude modulated (AM).
Page 57: Ac Modules
CHAPTER 3: INSTALLATION WIRING • DC power: 110, 125, 220, or 250 V DC • AC power: 115 or 230 V AC Control power supplied to the relay must be connected to the matching power supply FASTPATH: range of the relay. If the voltage is applied to the wrong terminals, damage can occur. Plus The D90 system, like almost all electronic relays, contains electrolytic capacitors.
Page 58 WIRING CHAPTER 3: INSTALLATION currents from one breaker, while channels 4 through 6 are connected to the phase A, B, and C currents from the second breaker. The phase current channels are used for most metering and protection purposes. Channel 7 can be used for either of two purposes. First, it can be connected to a CT that is directly measuring system ground current.
Page 59: Contact Input And Output Modules
CHAPTER 3: INSTALLATION WIRING Figure 24: Typical AC module wiring Contact input and output modules Each contact input/output module has 24 terminal connections. They are arranged in two terminals per row, with twelve rows in total. A given row of two terminals can be used for the outputs of one relay.
Page 60 WIRING CHAPTER 3: INSTALLATION Form-A and solid-state relay output contacts Some form-A and solid-state relay (SSR) outputs include circuits to monitor the DC voltage across the output contact when it is open, and the DC current through the output contact when it is closed.
Page 61 CHAPTER 3: INSTALLATION WIRING other contact input terminal. The maximum external source voltage for this arrangement is 300 V DC. The voltage threshold at which each group of four contact inputs will detect a closed contact input is programmable as from 24 to 250 V DC. Wherever a tilde “~”...
Page 62 WIRING CHAPTER 3: INSTALLATION Figure 28: Terminal block pin view Table 2: Module configuration Contact input/output module Type A Type B Type C Type D Type E Type F 1A Form-A output SSR output 1 + Form-A output Form-A output Contact input Form-A output 1B Form-A output...
Page 63: Inter-Relay Communication Modules
CHAPTER 3: INSTALLATION WIRING Contact input/output module Type A Type B Type C Type D Type E Type F 6B Contact input Contact input Contact input Form-A output Contact input Form-A output 2 – 2 – 2 – 6 – 12 + 6 –...
Page 64 WIRING CHAPTER 3: INSTALLATION Figure 29: Direct input and output dual channel connection The interconnection requirements are described in further detail in this section for each inter-relay communication module, which is specified at the time of ordering. The table lists these modules. All fiber modules use ST type connectors. Table 3: Inter-relay communication modules Order code Specification...
Page 65 CHAPTER 3: INSTALLATION WIRING Figure 30: Link LEDs for fiber, RS422, and G.703 modules The table describes the operation of the link LEDs. Table 4: Link LED operation Protocol LED indications Red, solid Green, solid Green, blinking Yellow, blinking IEEE Loss of Signal detected, Signal detected...
Page 66 WIRING CHAPTER 3: INSTALLATION G.703 communication interface AWG 24 twisted shielded pair is recommended for external connections, with the shield grounded only at one end. Connecting the shield to pin B1a or B8a grounds the shield since these pins are internally connected to ground. Thus, if pin B1a or B8a is used to ground the shield at one end, do not ground the shield at the other end.
Page 67 CHAPTER 3: INSTALLATION WIRING Figure 33: RS422 interface connections The following figure shows the typical pin interconnection between two dual-channel RS422 interfaces. All pin interconnections are to be maintained for a connection to a multiplexer. Figure 34: Typical connection between two RS422 interfaces Each channel of the RS422 interface accepts a clock input for transmit timing.
Page 68 WIRING CHAPTER 3: INSTALLATION Figure 35: Clock and data transitions The RS422 interface utilizes NRZI-MARK modulation code and therefore does not rely on an Rx clock to recapture data. NRZI-MARK is an edge-type, invertible, self-clocking code. To recover the Rx clock from the data-stream, an integrated digital phase lock loop (DPLL) circuit is utilized.
Page 69: Install Software
CHAPTER 3: INSTALLATION INSTALL SOFTWARE Plus The UR -series C37.94 communication module can be connected to the electrical interface (G.703, RS422, or X.21) of a non-compliant digital multiplexer via an optical-to- electrical interface converter that supports the IEEE C37.94 standard. The following figure shows the concept.
Page 70: Install Software
INSTALL SOFTWARE CHAPTER 3: INSTALLATION • USB 2.0 or Ethernet port • Internet access or CD drive Plus The software and unit are backwards-compatible with UR -series devices having any previous firmware version. Install software Plus After ensuring that the requirements for using EnerVista UR Setup software are met, install the software from the CD, or download EnerVista Launchpad software from http:// www.gedigitalenergy.com/multilin and install it.
Page 71 CHAPTER 3: INSTALLATION INSTALL SOFTWARE Figure 40: Identifying the device type Select the complete path, including the new directory name, where the EnerVista Plus Setup is to be installed. Click the Next button to begin the installation. The files are installed in the directory indicated, and the installation program automatically creates icons and adds an entry to the Windows start menu.
Page 72: Connect For First Time With Quick Connect
INSTALL SOFTWARE CHAPTER 3: INSTALLATION Plus Figure 41: UR -series device added to Launchpad window Connect for first time with Quick Connect Plus The most convenient way to establish communication to the D90 for the first time using Plus the EnerVista UR Setup software is to use the USB interface located on the front of the relay.
Page 73: Configure The D90 Plus For Software Access
Warn or Ignore. Then restart the hardware wizard in the Control Panel by clicking Administrative Tools, then Computer Management, then Device Manager, and search for the GE Protective Relay entry. Reinstall the driver. Launch the EnerVista software, and click the Quick Connect icon to open the Quick Connect window.
Page 74 INSTALL SOFTWARE CHAPTER 3: INSTALLATION (slot C communications module). Plus On the computer, select the “UR ” device from the EnerVista Launchpad to start Plus EnerVista UR Setup. Click the Device Setup button to open the Device Setup window, then click the Add Site button to define a new site.
Page 75 Plus the D90 , a GE Digital Energy F485 converter (or compatible RS232-to-RS485 converter) is required. See the F485 instruction manual for details. Connect the computer to the F485 and the F485 to the RS485 terminal on the back of...
Page 76: Activate The D90 Plus
INSTALL SOFTWARE CHAPTER 3: INSTALLATION 11. Click OK button when the relay order code has been received. The new device is added to the Site List window (or Online window) located in the top left corner of the Plus main EnerVista UR Setup window.
Page 77 CHAPTER 3: INSTALLATION INSTALL SOFTWARE Plus See the software chapter or the EnerVista UR Setup help file for more information about the using the software interface. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 78 INSTALL SOFTWARE CHAPTER 3: INSTALLATION PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 79: Front Panel
Plus Line Distance Protection System Chapter 4: Front panel interface Front panel interface This chapter explains use of the front panel interface. Front panel Plus The front panel provides an interface with the D90 . It includes two color liquid crystal displays (LCDs) (annunciators) and two sets of user-programmable pushbuttons.
Page 80 FRONT PANEL OPERATION CHAPTER 4: FRONT PANEL INTERFACE Figure 43: Front panel interface Front panel operation The front panel has two displays and several pushbuttons. The control pushbuttons are shown only in the control menu. Otherwise, the menu navigation pushbuttons are shown. The number of control pushbuttons depends on the number of disconnects and breakers in the selected mimic diagram.
Page 81: Front Panel Interface
CHAPTER 4: FRONT PANEL INTERFACE METERING MENU Figure 44: Front panel interface operation The following figure shows a typical menu structure. The structure for any specific Plus varies according to its order code. Figure 45: Menu structure Metering menu The system metering quantities are available from the front panel in the metering menu. These values are derived automatically from the metering source.
Page 82: Control Menu
CONTROL MENU CHAPTER 4: FRONT PANEL INTERFACE The following three fixed metering screens are also available: • The energy page displays and allows the user to reset four quadrant energy values • The phasor screen graphically displays the phasor components of the system voltage (phase-neutral) and current for the selected metering source •...
Page 83: Digital Fault Recorder Menu
CHAPTER 4: FRONT PANEL INTERFACE DIGITAL FAULT RECORDER MENU display of current phase angle The front panel control pushbuttons can be placed under password security. When password security is enabled, the front panel requests the command password before performing any actions. Use the Next button to access additional alphanumeric characters.
Page 84 DIGITAL FAULT RECORDER MENU CHAPTER 4: FRONT PANEL INTERFACE Figure 50: Digital fault recorder - example summary page The sequence of events record can be accessed from this page. Using the navigations keys, scroll or page through the events list. Two cursors are provided for measurement of the time difference between events.
Page 85: Equipment Manager Menu
CHAPTER 4: FRONT PANEL INTERFACE EQUIPMENT MANAGER MENU Records can be retrieved and deleted, and triggers can be generated manually from this screen. Figure 53: Example of transient record The digital fault recorder menu disturbance record menu lists all disturbance records Plus stored in the D90 .
Page 86: Annunciator
ANNUNCIATOR CHAPTER 4: FRONT PANEL INTERFACE Figure 55: Equipment manager battery alarms example Annunciator An annunciator is a color panel on the front of the unit. Annunciator operation The annunciator supports three types of alarms: self-reset, latched, and acknowledgeable. Each location in an annunciator display page can be configured to be one of the three alarm types and can also display an optional metered value.
Page 87 CHAPTER 4: FRONT PANEL INTERFACE ANNUNCIATOR • The Next Alarm button navigates horizontally through the current alarms that are active, from left-to-right, starting with the first row of alarms. A border is drawn around the current alarm. • The Ack/Reset button is used to acknowledge alarms or reset latched and acknowledgeable alarms that are in the ringback state.
Page 88: Self-Test Page
ANNUNCIATOR CHAPTER 4: FRONT PANEL INTERFACE Self-test page This page displays any active self-test alarms as well as the time of occurrence and the severity of the alarm (yellow for non-critical and red for critical). Figure 58: Self-test page example Product information page The product information page contains data describing the device, including the order code, serial number, device identification name, setting configuration name, time of last...
Page 89 CHAPTER 4: FRONT PANEL INTERFACE ANNUNCIATOR The configured IP protocol values display for each of the available Ethernet ports. Ethernet port 1 is the port on the main CPU card in slot D, while port 2 is located at the top of the slot C communications processor and port 3 at the bottom.
Page 90 ANNUNCIATOR CHAPTER 4: FRONT PANEL INTERFACE PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 91: Enervista Software
Plus Line Distance Protection System Chapter 5: EnerVista software EnerVista software Plus This chapter describes the EnerVista UR Setup software. Introduction Plus The EnerVista UR Setup software provides a graphical user interface (GUI) to configure, Plus monitor, maintain, and troubleshoot the operation of UR -series devices connected locally to a computer or over local or wide area communications networks.
Page 92: Enable The Settings Template In Offline Mode
SETTINGS TEMPLATES CHAPTER 5: ENERVISTA SOFTWARE The settings template mode allows the user to define which settings are visible in the software. Settings templates can be applied to both settings files (settings file templates) and online devices (online settings templates). The functionality is identical for both purposes.
Page 93: Add Password Protection To A Template
CHAPTER 5: ENERVISTA SOFTWARE SETTINGS TEMPLATES If prompted, enter the template password then click OK. Open the relevant settings windows that contain settings to be specified as viewable. By default, all settings are specified as locked and displayed against a grey background.
Page 94: View The Settings Template
SETTINGS TEMPLATES CHAPTER 5: ENERVISTA SOFTWARE The software prompts for a template password. This password must be at least four characters in length. Figure 62: Template password entry window Enter and re-enter the new password, then click OK to continue. The settings file template is now secured with password protection.
Page 95: Remove The Settings Template
CHAPTER 5: ENERVISTA SOFTWARE SECURE AND LOCK FLEXLOGIC EQUATIONS Figure 64: Applying templates using the View in Template Mode settings command Remove the settings template It can be necessary at some point to remove a settings template. Once a template is removed, it cannot be reapplied and a new settings template needs to be defined before use.
Page 96: Lock Flexlogic Equations
SECURE AND LOCK FLEXLOGIC EQUATIONS CHAPTER 5: ENERVISTA SOFTWARE Secured FlexLogic equations remain secure when files are sent to and retrieved from any Plus -series device. Locking can be tied to the serial number too. Lock FlexLogic equations To lock individual entries of a FlexLogic equation: Right-click the settings file or online device and select the Template Mode >...
Page 97: Settings File Traceability
CHAPTER 5: ENERVISTA SOFTWARE SETTINGS FILE TRACEABILITY Plus Enter the serial number of the D90 device to lock to the settings file in the Serial # Lock field. Click the OK button to apply the change. The settings file and corresponding secure FlexLogic equations are now locked to the Plus device specified by the serial number.
Page 98: Settings File Traceability Information
SETTINGS FILE TRACEABILITY CHAPTER 5: ENERVISTA SOFTWARE Figure 66: Settings file traceability With respect to the figure, the traceability feature is used as follows. Plus The transfer date of a settings file written to a D90 is logged in the device and can be viewed in the EnerVista software or the front panel display.
Page 99: Online Device Traceability Information
CHAPTER 5: ENERVISTA SOFTWARE SETTINGS FILE TRACEABILITY Figure 68: Settings file report showing traceability data Online device traceability information Plus The D90 serial number and file transfer date are available for an online device through the actual values. Select the Actual Values > Product Information > Model Information menu item within the EnerVista online window as shown in the example.
Page 100 SETTINGS FILE TRACEABILITY CHAPTER 5: ENERVISTA SOFTWARE PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 101: Communications Communications Overview
Plus Line Distance Protection System Chapter 6: Communications Communications Plus This chapter outlines how to program the D90 communications settings. Communications overview Plus The D90 has one Ethernet port (port 1) on the main CPU module in slot D and two Ethernet ports (ports 2 and 3) on the communications module in slot C.
Page 102 COMMUNICATIONS OVERVIEW CHAPTER 6: COMMUNICATIONS Figure 70: Simple network topology without communications cards The topology shown as follows allows SCADA, GOOSE, configuration, and monitoring functions to share a single network. No redundancy is provided. A communications Plus processor is required in each D90 device to facilitate SCADA and GOOSE messaging.
Page 103 CHAPTER 6: COMMUNICATIONS COMMUNICATIONS OVERVIEW Figure 72: Simple single network topology with redundancy The following topology illustrates a dual LAN network. Configuration and monitoring functions are provided on LAN 1 with no redundancy. LAN 2 is dedicated to SCADA and GOOSE communications and includes redundant hardware and media.
Page 104: Network Settings
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS Figure 74: Simple dual redundant network topology The following topology illustrates a dedicated LAN for configuration and monitoring Plus functions and dual redundant LANs for SCADA and GOOSE traffic. Each D90 device services clients on either network as required. GOOSE messages are transmitted and received on both LANs simultaneously.
Page 105: Ethernet Ports
CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS Ethernet ports The Ethernet ports can be configured for single IP, dual IP, or redundancy using the Parallel Redundancy Protocol (PRP). The single IP redundancy configuration provides compatibility with UR-series relays and other devices with single-IP redundancy. In this configuration, the port 2 IP address, subnet mask, and gateway address are used and the port 3 settings are ignored.
Page 106 NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS The following settings are available for each Ethernet port, except for OSI Network Address , which are not port-specific, and the (NSAP) ESH Configuration Time Port 2 , which applies only to Ethernet port 2. Redundancy Port 1 IP Address, Port 2 IP Address, Port 3 IP Address Range: standard IP address range...
Page 107 CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS – Port 3 is in a standby mode in that it does not actively communicate on the Ethernet network but monitors its link to the Multilink switch. If port 2 detects a problem with the link, communications is switched to port 3. Port 3 is, in effect, acting as a redundant or backup link to the network for port 2.
Page 108: Tftp Protocol
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS – “PORT 1 NETMASK ERROR”, “PORT 2 NETMASK ERROR”, “PORT 3 NETMASK ERROR” — An invalid network mask value was entered for Ethernet port 1, 2, or 3, respectively. – “PORT 1 IP ADDR RSVD”, “PORT 2 IP ADDR RSVD”, “PORT 3 IP ADDR RSVD” — A reserved IP address was entered for Ethernet port 1, 2, or 3, respectively.
Page 109: Sntp Protocol
CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS Figure 77: TFTP configuration settings The following settings are available. Main UDP Port Number Range: 1 to 65535 in steps of 1 Default: 69 This setting specifies the main UDP port number. TFTP Data UDP Port Number 1, TFTP Data UDP Port Number 2, TFTP Data UDP Port Number 3, TFTP Data UDP Port Number 4 Range: 0 to 65535 in steps of 1 Default: 0...
Page 110: Http Protocol
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS Figure 78: SNTP configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the SNTP protocol. Server IP Address Range: standard IP address Default: 0.0.0.0 This setting specifies the SNTP/NTP server IP address. To use SNTP in unicast mode, this setting must be programmed to the SNTP/NTP server Plus IP address.
Page 111: Network Filtering
CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS Figure 79: Sample web access page Select the Settings > Communications > Network > HTTP menu item to open the HTTP configuration window. Figure 80: HTTP configuration settings The following settings are available. HTTP TCP Port Number Range: 1 to 65535 in steps of 1 Default: 80 This setting specifies the TCP port number for the embedded web server.
Page 112: Ethernet Actual Values
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS Figure 81: Network filtering configuration settings The following settings are available. Port 1 Bandwidth Limitation Range: Disabled, Enabled Default: Disabled This setting is used to enable IP protocol bandwidth limiting on Ethernet port 1. The Plus COMM HIGH TRAFFIC self-test message is issued when the D90 is actively limiting IP...
Page 113: Remaining Tcp/Ip Connections
CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS Port 1 Ethernet Duplex, Port 2 Ethernet Duplex, Port 3 Ethernet Duplex Range: Full Duplex, Half Duplex This actual value indicates the Ethernet duplex mode on each of the three ports. Port 1 Ethernet Speed, Port 2 Ethernet Speed, Port 3 Ethernet Speed Range: 10 Mbps, 100 Mbps This actual value indicates the network speed on each of the three Ethernet ports.
Page 114: Prp Actual Values
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS DNP Available TCP/IP Connections Range: 0, 1, 2 This actual value indicates the number of connections available for DNP communications. The number of DNP connections is zero unless the “Network - TCP” value has been selected for both the DNP Channel 1 Port DNP Channel 2 Port settings.
Page 115: Modbus Communications
CHAPTER 6: COMMUNICATIONS MODBUS COMMUNICATIONS Figure 85: Date and time actual values and commands The following actual values display. Computer Date Range: date in MM/DD/YY format This actual value displays the date specified by the computer running the EnerVista Plus Setup software.
Page 116: Modbus Protocol
MODBUS COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Plus See the D90 Communications Guide for information on developing communication drivers and for the Modbus memory map. The map is also viewable in a web browser; Plus enter the IP address of the D90 in a web browser and click the option.
Page 117: Dnp Communications
CHAPTER 6: COMMUNICATIONS DNP COMMUNICATIONS Select the Settings > Communications > Modbus > User Map menu to open the Modbus user map configuration window. Figure 87: Modbus user map configuration settings The following settings are available for each of the 256 registers. Modbus Type Range: None, Settings, Actuals Default: None...
Page 118 DNP COMMUNICATIONS CHAPTER 6: COMMUNICATIONS operating any output present in the device. Both direct-operate and select-before-operate modes of control are supported. Two user-configurable input and output maps are implemented. Select the Settings > Communications > DNP > Protocol menu to open the DNP protocol configuration window.
Page 119 CHAPTER 6: COMMUNICATIONS DNP COMMUNICATIONS DNP Channel Address Range: 0 to 65519 in steps of 1 Default: 1 Plus This setting specifies the DNP slave address. This number identifies the D90 on a DNP communications link. Assign a unique address to each DNP slave. DNP Client Address 1, DNP Client Address 2,..., DNP Client Address 5 Range: any standard IP address Default: 0.0.0.0...
Page 120 DNP COMMUNICATIONS CHAPTER 6: COMMUNICATIONS DNP Current Default Deadband, DNP Voltage Default Deadband, DNP Power Default Deadband, DNP Power Factor Default Deadband, DNP Other Default Deadband Range: 0 to 100000000 in steps of 1 Default: 30000 These settings determine when to trigger unsolicited responses containing analog input Plus data.
Page 121: Dnp User Point List
CHAPTER 6: COMMUNICATIONS DNP COMMUNICATIONS reverse paired order, meaning that is starts backward from the end of the Control Outputs List. For example, when the DNP Number of Paired Controls setting is configured as 4, the DNP Points Lists web page shows Automation Virtual Inputs 121 to 128 are paired, as shown in the figure.
Page 122: Iec 60870-5-104 Communications
IEC 60870-5-104 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 90: DNP user point list configuration settings The following settings are available for points 0 through 255. DNP Binary Input Point 0, DNP Binary Input Point 1,..., DNP Binary Input Point 255 Range: any FlexLogic operand Default: Off These settings represent DNP binary input points and are configured by assigning an appropriate FlexLogic operand to each.
Page 123 CHAPTER 6: COMMUNICATIONS IEC 60870-5-104 COMMUNICATIONS Figure 91: IEC 60870-5-104 protocol configuration settings The following settings are available. Do not set more than one protocol to the same TCP/UDP port number, as this results in NOTE: unreliable operation of those protocols. IEC TCP Port Number Range: 0 to 65535 in steps of 1 Default: 2404...
Page 124: Iec 60870-5-104 Point Lists
IEC 60870-5-104 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Plus responses from the D90 when any current values change by 15 amps, set the setting to “15.” Note that these settings are the default values Current Default Threshold of the deadbands. P_ME_NC_1 (parameter of measured value, short floating point value) points can be used to change threshold values, from the default, for each individual Plus M_ME_NC_1 analog point.
Page 125: Iec 61850 Communications
CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS IEC 61850 communications Plus The D90 supports the Manufacturing Message Specification (MMS) protocol as specified by IEC 61850. MMS is supported over the TCP/IP over Ethernet protocol stack. Polling, unbuffered reporting, and buffered reporting are supported. Direct operate and select- before-operate are supported.
Page 126 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 94: GSSE transmission configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables GSSE transmission. Range: up to 65 ASCII characters Default: GSSEOut This setting represents the IEC 61850 GSSE application ID name string sent as part of each GSSE message.
Page 127 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 95: Fixed GOOSE transmission configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables fixed GOOSE transmission. Range: up to 65 ASCII characters Default: GOOSEOut This setting represents the IEC 61850 GOOSE application ID (GoID) name string sent as part of each GOOSE message.
Page 128 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS GOOSE ETYPE APPID Range: 0 to 16383 in steps of 1 Default: 0 This setting allows the selection of a specific application ID for each GOOSE sending device. This value can be left at its default if the feature is not required. This setting is required by IEC 61850.
Page 129 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS The following settings are available for each dataset for configurable GOOSE transmission. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables configurable GOOSE transmission. Range: up to 65 ASCII characters Default: GOOSEOut_1 This setting represents the IEC 61850 GOOSE application ID (GoID) name string sent as part of each GOOSE message.
Page 130 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Retransmission Profile Range: None, Aggressive, Standard, Relaxed Default: Standard Plus The D90 supports four retransmission schemes: aggressive, standard, relaxed, and none. The following retransmission times are specified under these profiles. – Aggressive — Select for trip schemes — 4, 8, 16, 32, and 64 ms –...
Page 131 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Dataset Item 1, Dataset Item 2, Dataset Item 3,..., Dataset Item 64 Range: all valid MMS data item references for transmitted data Default: 0 These settings are used to select an MMS data item for each configurable GOOSE dataset item.
Page 132 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 98: Remote devices configuration settings The following settings are available for each of the 32 remote devices. Range: up to 65 alphanumeric characters Default: Remote Device 1 Up to 32 remote devices can be selected for setting purposes. A receiving relay must be programmed to capture messages from the originating remote devices of interest.
Page 133 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS defined by the user selection of the FlexLogic operand whose state is represented in the GSSE/GOOSE message. A user must program a DNA point from the appropriate FlexLogic operand. Table 6: IEC 61850 DNA Assignments IEC 61850 definition FlexLogic operand Test...
Page 134 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS – Off — Defaults the input to logic 0 – Latest/On — Freezes the input in case of lost communications. If the latest state is not known, such as after relay power-up but before the first communication exchange, the input defaults to logic 1.
Page 135 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Name Range: up to 12 alphanumeric characters Default: RemDPS Ip 1 This setting specifies an exact identification (ID) for each remote double-point status input. Device Range: Remote Device 1 through Remote Device 32 Default: Remote Device 1 This setting selects a remote device ID to indicate the origin of a GOOSE message.
Page 136 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 101: Remote outputs DNA bit pair configuration settings The following settings are available for each of the 32 remote outputs. Operand Range: any automation logic or FlexLogic operand Default: Off This setting specifies the FlexLogic operand assigned to DNA point 1. Events Range: Enabled, Disabled Default: Disabled...
Page 137 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 102: Remote output UserSt bit pair configuration settings The following settings are available for each of the 32 bit pairs. Operand Range: any FlexLogic operand Default: Off This setting specifies the FlexLogic operand assigned to UserSt point 1. Events Range: Enabled, Disabled Default: Disabled...
Page 138: Iec 61850 Server Configuration
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS The following settings are available for each of the 128 IEC 61850 GOOSE analog inputs. Default Value Range: –1000000.000 to 1000000.000 in steps of 0.001 Default: 1000.000 This setting specifies the value of the GOOSE analog input when the sending device is offline and the Default Mode setting is set to “Default Value.”...
Page 139 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 104: IEC 61850 server configuration settings The following settings are available. IED Name Range: up to 32 alphanumeric characters Default: IEDName This setting represents the MMS domain name where all IEC/MMS logical nodes are located.
Page 140: Logical Node Prefixes
61850 standard. Additional details regarding the logical node naming rules are provided in IEC 61850 standard parts 6 and 7-2. GE Digital Energy recommends that a consistent naming convention be used for an entire substation project. Select the Settings > Communications > IEC 61850 > Logical Node Prefixes menu item to open the IEC 61850 logical node prefixes configuration window.
Page 141 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS MMXU1 LN Prefix through MMXU4 LN Prefix Range: six character ASCII string Default: empty These settings specify the prefixes for measured quantity logical nodes 1 through 4. PIOC1 LN Prefix through PIOC14 LN Prefix Range: six character ASCII string Default: empty These settings specify the prefixes for instantaneous overcurrent logical nodes 1...
Page 142: Mmxu Deadbands
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS RREC1 LN Prefix Range: six character ASCII string Default: empty This setting specifies the prefix for the autoreclose logical node. RSYN1 LN Prefix, RSYN2 LN Prefix Range: six character ASCII string Default: empty These settings specify the prefixes for the synchrocheck logical nodes 1 and 2. XCBR1 LN Prefix through XCBR2 LN Prefix Range: six character ASCII string Default: empty...
Page 143 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 106: IEC 61850 MMXU deadband configuration settings The following settings are available for each of the four MMXU nodes. Total Watt Deadband Range: 0.001 to 100.000% in steps of 0.001 Default: 10.000% This setting specifies the real power deadband value. The maximum value representing 100% of deadband is 46 ×...
Page 144: Ggio1 Status Configuration
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS PhV Phase A Deadband, PhV Phase B Deadband, PhV Phase C Deadband Range: 0.001 to 100.000% in steps of 0.001 Default: 10.000% These settings specify the Va, Vb, and Vc phase voltage deadband values. The 100% deadband value is 275 ×...
Page 145: Ggio2 Control Configuration
CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS display screens. Buffered reporting should generally be used for SOE logs since the buffering capability reduces the chances of missing data state changes. Use unbuffered reporting for local status display. Select the Settings > Communications > IEC 61850 > GGIO1 Status Configuration menu to open the GGIO1 status configuration window.
Page 146: Ggio4 Analog Configuration
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 108: IEC 61850 GGIO2 control configuration The following setting is available for each of the 64 GGIO2 control points. Each control Plus point is mapped to a corresponding D90 protection virtual input. For example, GGIO2 control point SPCSO 3 is mapped to protection virtual input 3.
Page 147 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 109: IEC 61850 GGIO4 analog configuration The following settings are available. IEC 61850 GGIO4 Analogs Range: 4 to 32 in steps of 4 Default: 4 This setting specifies how many analog data points exist in GGIO4. When this value is Plus changed, the D90 must be restarted to allow the GGIO4 logical node to be re-...
Page 148: Ggio5 Control Configuration
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS IEC 61850 GGIO4 Analog 1 Maximum Range: –1000000000.000 to 1000000000.000 in steps of 0.001 Default: 0.000 These settings specify the maximum value for each analog value.See IEC 61850-7-1 and IEC 61850-7-3 for details. This maximum value is used to determine the deadband. The deadband is used in the determination of the deadbanded magnitude from the instantaneous magnitude.
Page 149: Unbuffered Report Control Configuration
CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS SPCSO 1 ctlModel Range: 0, 1, 2 Default: 1 The GGIO5 control configuration settings are used to set the control model for each input. The available choices are “0” (status only), “1” (direct control), and “2” (SBO with normal security).
Page 150: Buffered Report Control Configuration
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Unbuffered Reports BufTm Range: 0 to 4294967295 in steps of 1 Default: 0 This setting specifies the buffer time. Unbuffered Reports TrgOps Range: 0 to 65535 in steps of 1 Default: 0 This setting specifies a bitmask that selects the trigger options. The following bits are Plus supported by the D90 –...
Page 151: Iec 61850 Actual Values
CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Buffered Reports OptFlds Range: 0 to 65535 in steps of 1 Default: 0 This setting specifies a bitmask that selects the option fields. The following bits are Plus supported by the D90 – Bit 1 — Sequence-number –...
Page 152 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS The following actual values are available for the IEC 61850 remote devices. The name and status are available for each remote device. All Remote Devices Online Range: Yes, No This value indicates whether or not all programmed remote devices are online. If the corresponding state is “No,”...
Page 153 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 115: Remote double-point status input actual values The following actual values are available for each remote double-point status input. Name Range: up to 12 alphanumeric characters This value displays the name programmed for the corresponding remote double-point status input.
Page 154: Flexstates
FLEXSTATES CHAPTER 6: COMMUNICATIONS IEC 61850 GOOSE analog input actual values Select the Actual Values > Communications > Inputs/Outputs > IEC61850 GOOSE Analog Inputs menu to open the IEC 61850 GOOSE analog input actual values window. Figure 117: IEC 61850 GOOSE analog input actual values The following actual value is available for each IEC 61850 GOOSE analog input.
Page 155: Flexstate Actual Values
CHAPTER 6: COMMUNICATIONS FLEXSTATES Figure 118: FlexStates configuration settings The following settings are available. Parameter 1 through Parameter 256 Range: any FlexLogic operand Default: Off These settings assign FlexLogic parameters to each of the 256 FlexStates. The FlexState register array begins at Modbus address 0900h. FlexState actual values Select the Actual Values >...
Page 156: Real-Time Clock
REAL-TIME CLOCK CHAPTER 6: COMMUNICATIONS Name Range: any FlexLogic operand This actual value indicates the FlexLogic operand assigned to the FlexState parameter. Value Range: OFF, ON This actual value indicates the logic state (ON, OFF) of the FlexState parameter. Real-time clock The date and time can be synchronized to a known time base and to other devices using Plus an IRIG-B signal.
Page 157 CHAPTER 6: COMMUNICATIONS REAL-TIME CLOCK Time Zone Offset Range: –24.0 to 24.0 hours in steps of 0.5 Default: 0.0 hours This setting specifies the local time zone offset from Greenwich Mean Time (GMT) in Plus hours. This setting has two uses. When the D90 is time synchronized with IRIG-B, or has no permanent time synchronization, the offset is used to calculate Universal Plus...
Page 158: User-Programmable Self-Tests
USER-PROGRAMMABLE SELF-TESTS CHAPTER 6: COMMUNICATIONS DST Stop Hour Range: 0 to 23 in steps of 1 Default: 2 This setting specifies the hour at which daylight saving time ends. For example, if daylight saving time ends at 4:00 AM, program this setting to “4.” User-programmable self-tests All major self-test alarms are reported automatically with their corresponding FlexLogic operands.
Page 159 CHAPTER 6: COMMUNICATIONS USER-PROGRAMMABLE SELF-TESTS Ethernet Port 3 Fail Function Range: Enabled, Disabled Default: Disabled When this setting is “Disabled,” the ETHERNET PORT 3 FAILURE alarm does not assert a FlexLogic operand or write to the event recorder. Moreover, it does not trigger the ANY MINOR ALARM or ANY SELF-TEST messages.
Page 160: Serial Port
SERIAL PORT CHAPTER 6: COMMUNICATIONS Serial port Plus The D90 is equipped with one serial RS485 communication port, located on the main processor module in slot D at the back of the unit. The RS485 port has settings for baud rate and parity.
Page 161: Direct Input And Output Configuration
CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS additional switching equipment is required as the IEDs are connected directly in a ring or redundant (dual) ring configuration. This feature is optimized for speed and intended for pilot-aided schemes, distributed logic applications, or the extension of the input/output capabilities of a single device.
Page 162 DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Figure 123: Direct inputs/outputs configuration settings The following setting is available and applicable to both channels in all direct inputs and direct outputs. Direct Device ID Range: 1 to 16 in steps of 1 Default: 1 Plus This setting identifies the D90...
Page 163 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS CRC Alarm Count Range: 100 to 10000 in steps of 1 Default: 600 When the total message counter reaches the user-defined maximum specified by this setting, both the counters reset and the monitoring process is restarted. Plus To monitor communications integrity, the D90 sends one message per second (at...
Page 164: Direct Input And Output Examples
DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS configured to drive an output contact, annunciator alarm, or selected communication- based output. Latching and acknowledging conditions, if required, need to be programmed accordingly in the annunciator settings. Message Alarm Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of unreturned message alarm events in the sequence of events recorder.
Page 165 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Figure 126: Direct input and output settings for IED 1 Plus For UR -series IED 2: Figure 127: Inter-relay communications settings for IED 2 Figure 128: Direct input and output settings for IED 2 The message delivery time is about 0.2 of power cycle in both ways (at 128 kbps);...
Page 166 DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Figure 129: Interlocking busbar protection scheme example For increased reliability, a dual-ring configuration is recommended for this application, shown as follows. Figure 130: Interlocking busbar protection scheme via direct inputs and outputs The following settings are applied to implement this application. For IED 1, set the inter- relay application for both channels as follows in the Settings >...
Page 167 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Figure 132: Inter-relay communications settings for IEDs 2 through 4 Plus For UR -series IED 1: Figure 133: Direct input and output settings for IED 1 Plus For UR -series IED 2: Figure 134: Direct input and output settings for IED 2 Plus For UR -series IED 3:...
Page 168 DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Figure 135: Direct input and output settings for IED 3 Plus For UR -series IED 4: Figure 136: Direct input and output settings for IED 4 Message delivery time is approximately 0.2 of power system cycle (at 128 kbps) multiplied by the number of bridges between the origin and destination.
Page 169 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Path Delivery time IED 1 to IED 3 0.4 of a power system cycle IED 1 to IED 4 0.6 of a power system cycle IED 2 to IED 3 0.2 of a power system cycle IED 2 to IED 4 0.4 of a power system cycle IED 3 to IED 4...
Page 170 DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Figure 139: Inter-relay communications settings for IED 1 Figure 140: Inter-relay communications settings for IEDs 2 through 3 Plus For UR -series IED 1: Figure 141: Direct input and output settings for IED 1 Plus For UR -series IED 2:...
Page 171: Direct Input And Output Statistics
CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Figure 143: Direct input and output settings for IED 3 In this configuration the following delivery times are expected (at 128 kbps) when both rings are healthy. Table 11: Expected delivery times for healthy rings Path Delivery time IED 1 to IED 2...
Page 172: Direct Input And Output Commands
TELEPROTECTION INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS CRC Fail Count Range: 0 to 65535 in steps of 1 These actual values (one per communications channel) display the number of direct output messages that have been received but fail the CRC check. High values can indicate a problem with wiring or the communication channel on one or more devices.
Page 173: Teleprotection Settings
CHAPTER 6: COMMUNICATIONS TELEPROTECTION INPUTS AND OUTPUTS Teleprotection settings Select the Settings > Communications > Teleprotection menu item to open the main teleprotection configuration window. Figure 146: Teleprotection configuration settings The following teleprotection settings are available. Local Relay ID Range: 0 to 255 in steps of 1 Default: 0 In installations that use multiplexers or modems, a good practice is to ensure that the data used by the devices protecting a given line is from the correct device.
Page 174: Teleprotection Commands
INTER-RELAY COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Status Range: n/a, Fail, OK This actual value is the receiver status for each channel. If the value is “OK,” teleprotection is enabled and data is being received from the remote terminal. If the value is “Fail,” teleprotection is enabled and data is not being received from the remote terminal.
Page 175: Inter-Relay Communication Actual Values
CHAPTER 6: COMMUNICATIONS INTER-RELAY COMMUNICATIONS If the application is different for a channel pair (channels 1 and 2), then the channels are treated independently and provide 96 inputs and outputs per channel. Select one of the redundancy values in cases where redundancy is important. Redundancy works on channel pairs (1 and 2).
Page 176 INTER-RELAY COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Select the Actual Values > Communications > Inter-Relay Transceivers menu to open the inter-relay communication actual values window. Figure 150: Inter-relay communication actual values The following actual values are available for each channel. Transceiver Temperature Range: –99.99 to 300.00 °C This value indicates the fiber transceiver temperature.
Page 177: Inter-Relay Communication Commands
CHAPTER 6: COMMUNICATIONS INTER-RELAY COMMUNICATIONS Transmit Power Level Trouble Range: On, Off This value indicates whether the fiber transceiver transmit power level is outside the manufacturer’s limit. Receive Power Level Range: –3276.8 to 3276.8 dBm in steps of 0.1 This value indicates the fiber transceiver receive power level. Receive Power Level Trouble Range: On, Off This value indicates the fiber transceiver receive power level is outside the...
Page 178: Communication Logic Operands
COMMUNICATION LOGIC OPERANDS CHAPTER 6: COMMUNICATIONS Communication logic operands Plus The following communication logic operands are available for the D90 . They are listed alphabetically by operand syntax. If required, these operands can be assigned user- defined names through the Settings > Configure FlexOperands menu. Direct device operands CH 1 DIR DEV 1 OFF........Asserted when direct device 1 on channel 1 is off.
Page 179: Communication Flexanalog Parameters
CHAPTER 6: COMMUNICATIONS COMMUNICATION FLEXANALOG PARAMETERS Figure 152: User-configurable communication logic operands window Plus The left side of this screen displays all operands that are currently available to the D90 The communication logic operands are displayed by expanding the Comms menu. User Configured Event Name Range: up to 20 alphanumeric characters Default: ---...
Page 180 COMMUNICATION FLEXANALOG PARAMETERS CHAPTER 6: COMMUNICATIONS PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 181: Protection Protection Overview
Plus Line Distance Protection System Chapter 7: Protection Protection Plus This chapter outlines how to program the D90 protection features. Protection overview Plus The D90 is intended for use on transmission lines of any voltage level, without, with, and in the vicinity of series compensation, in three-pole and single-pole tripping applications. The distance elements are optimized to provide good measurement accuracy with a sub- cycle operating time, even when used with capacitive voltage transformers, and can be supervised by detection of power swings.
Page 182 PROTECTION OVERVIEW CHAPTER 7: PROTECTION sets an operate flag when the input current has been at a level above the pickup setting for the time specified by the time-current curve settings. All comparators use analog actual values as the input. Protection elements are arranged into two classes, grouped and control.
Page 183: Power System
CHAPTER 7: PROTECTION POWER SYSTEM • setting — This setting is used to control whether the pickup, dropout, or Events operate states are recorded by the event recorder. When set to “Disabled,” element pickup, dropout, or operate are not recorded as events. When set to “Enabled,” events are created for –...
Page 184: Ac Input Modules
POWER SYSTEM CHAPTER 7: PROTECTION User Configuration Name Range: up to 20 alphanumeric characters Default: Initial This setting allows the user to provide a description for the settings that are loaded at a particular time (for example, “Spring-summer settings”). This description is displayed on the Product Information page of the front panel annunciator under the Configuration field.
Page 185 CHAPTER 7: PROTECTION POWER SYSTEM For three-phase channel groups, the number of the lowest numbered channel identifies the group. For example, J1 represents the three-phase channel set of J1, J2, and J3, where J is the slot letter and 1 is the first channel of the set of three channels. The first channel in the group is identified as phase A, the second channel as phase B, and the third channel as phase C.
Page 186 POWER SYSTEM CHAPTER 7: PROTECTION Ground CT Secondary Range: 1 A, 5 A Default: 5 A This setting selects the ground CT secondary value. It is used to derive secondary current values from per-unit settings used in protection elements. Current Cutoff Level Range: 0.002 to 0.020 pu in steps of 0.001 Default: 0.020 pu This setting modifies the current cut-off threshold.
Page 187 CHAPTER 7: PROTECTION POWER SYSTEM Phase VT Secondary Range: 50.0 to 240.0 volts in steps of 0.1 Default: 66.4 volts This setting specifies the nominal phase VT voltage for the corresponding voltage input. It is used typically to derive secondary voltage values from the per-unit settings used in protection elements.
Page 188 POWER SYSTEM CHAPTER 7: PROTECTION Calculating the power cut-off level Current Cutoff Level and the Voltage Cutoff Level settings are used to determine the metered power cut-off levels. The power cut-off level is calculated as shown here. For delta connections, the power cut-off is calculated as follows: Eq.
Page 189: Power System Frequency
CHAPTER 7: PROTECTION POWER SYSTEM Power system frequency Select the Settings > Protection > Power System > Frequency menu to open the power system frequency configuration window. Figure 158: System frequency configuration settings The following settings are available. Nominal Frequency Range: 50 Hz, 60 Hz Default: 60 Hz This value is used as a default to set the digital sampling rate if the system frequency...
Page 190: About Ac Sources
POWER SYSTEM CHAPTER 7: PROTECTION Frequency Tracking Range: Disabled, Enabled Default: Enabled This setting is set to “Disabled” only in unusual circumstances; consult GE Digital Energy for special variable-frequency applications. About AC sources Plus The D90 can be used on systems with breaker-and-a-half or ring bus configurations. In these applications, each of the two three-phase sets of individual phase currents (one associated with each breaker) can be used as an input to a breaker failure element.
Page 191 CHAPTER 7: PROTECTION POWER SYSTEM In conventional analog or electronic relays, the sum of the currents is obtained from an appropriate external connection of all CTs through which any portion of the current for the element being protected can flow. Auxiliary CTs are required to perform ratio matching if Plus the ratios of the primary CTs to be summed are not identical.
Page 192 POWER SYSTEM CHAPTER 7: PROTECTION It is possible to select the sum of two CTs for a protection source. The first channel displayed is the CT to which all others are referred. For example, the selection “J1+J4” indicates the sum of each phase from channels J1 and J4, scaled to whichever CT has the higher ratio.
Page 193: Grouped Protection Elements
CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 161: Disturbance detector logic Use of sources example Plus Consider a D90 connected as shown. This configuration can be used on a transmission line connected into a breaker-and-a-half system. The figure shows the arrangement of sources used to provide the functions required in this application, and the AC module inputs used to provide the data.
Page 194 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION overcurrent elements are used to identify a previously de-energized line that has been closed onto a fault. Faults other than close-in faults can be identified satisfactorily with the distance elements. Co-ordination features are included to ensure satisfactory operation when high-speed automatic reclosure is employed.
Page 195 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Phase IOC Line Pickup Range: 0.000 to 30.000 pu in steps of 0.001 Default: 1.000 pu This setting specifies the level of line current required to declare a line pickup operation when the line is re-energized. Undervoltage Pickup Range: 0.000 to 3.000 pu in steps of 0.001 Default: 0.700 pu...
Page 196 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Terminal Open Range: any FlexLogic operand Default: OFF This setting allows the line pickup element to be armed from a status signal (such as breaker position) rather than from current and voltage. The FlexLogic operand assigned to this setting indicates that the terminal is opened.
Page 197: Distance Elements
CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 164: Line pickup scheme logic Distance elements Four common settings are available for distance protection. Select the Settings > Protection > Elements > Group 1 > Distance > Common menu to open the distance configuration window.
Page 198 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 165: Shared distance settings The following settings apply to all phase and ground distance elements. There are five ground distance and five phase distance zones of protection in each setting group. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting identifies the signal source for all distance functions.
Page 199 Default: 1.00 ms This setting specifies the T1 parameter of the CVT filter. Disable the CVT filter function if this parameter is not known (do not use the default value). Contact GE Digital Energy for assistance in determining this setting.
Page 200 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 166: Memory voltage logic Impact of memory polarization Plus The D90 uses a memorized positive sequence voltage as a polarizing signal in order to achieve dependable operation for forward faults and secure non-operation for reverse faults.
Page 201 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 167: Phase distance configuration window (example) The following settings are available for each phase distance zone. There are five phase distance zones of protection in each setting group. Function Range: Enabled, Disabled Default: Enabled This setting enables and disables the phase distance protection feature.
Page 202 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 168: Directional mho phase distance characteristic Figure 169: Non-directional mho phase distance characteristic PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 203 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 170: Directional quadrilateral phase distance characteristic Figure 171: Non-directional quadrilateral phase distance characteristic Sample shapes for the mho and quadrilateral distance characteristics are shown as follows. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 204 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 172: Mho distance characteristic sample shapes PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 205 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 173: Quadrilateral distance characteristic sample shapes Transformer Voltage Connection Range: None, Dy1, Dy3, Dy5, Dy7, Dy9, Dy11, Yd1, Yd3, Yd5, Yd7, Yd9, Yd11 Default: None The phase distance elements can be applied to look through a three-phase delta-wye or wye-delta power transformer.
Page 206 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Transformer Current Connection Range: None, Dy1, Dy3, Dy5, Dy7, Dy9, Dy11, Yd1, Yd3, Yd5, Yd7, Yd9, Yd11 Default: None This setting specifies the location of the current source with respect to the involved power transformer in the direction of the zone. In section (a) of the following figure, zone 1 is looking through a transformer from the delta into the wye winding.
Page 207 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Range: 30 to 90° in steps of 1 Default: 85° This setting specifies the characteristic angle (similar to the “maximum torque angle” in previous technologies) of the phase distance characteristic for the forward and reverse applications.
Page 208 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Quadrilateral Right Blinder Range: 0.02 to 500.00 ohms in steps of 0.01 Default: 0.90 ohms This setting specifies the right blinder position of the quadrilateral characteristic along the resistive axis of the impedance plane (see the Quadrilateral Phase Distance Characteristic figures).
Page 209 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS The use of dynamic reach control by selection of a non-zero value for the Voltage Level NOTE: setting disables the subcycle operating time for that particular zone. Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.000 seconds This setting allows the user to delay operation of the distance elements and implement stepped distance protection.
Page 210 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 176: Phase distance zone 2 operation logic The following figure shows the phase distance scheme logic for zone 1. The logic is analogous for zones 2 through 5. Figure 177: Phase distance logic PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 211 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Ground distance settings The ground mho distance function uses a dynamic 100% memory-polarized mho characteristic with additional reactance, directional, current, and phase selection supervising characteristics. The ground quadrilateral distance function is composed of a reactance characteristic, right and left blinders, and 100% memory-polarized directional, overcurrent, and phase selection supervising characteristics.
Page 212 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 178: Ground distance settings configuration The following settings are available for each ground distance zone. There are five ground distance zones of protection in each setting group. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the phase distance protection feature.
Page 213 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 179: Directional mho ground distance characteristic Figure 180: Non-directional mho ground distance characteristic PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 214 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 181: Directional quadrilateral ground distance characteristic Figure 182: Non-directional quadrilateral ground distance characteristic PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 215 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Z0/Z1 Magnitude Range: 0.00 to 10.00 in steps of 0.01 Default: 2.70 This setting specifies the ratio between the zero-sequence and positive-sequence impedance required for zero-sequence compensation of the ground distance elements. This setting is available on a per-zone basis, enabling precise settings for tapped, non- homogeneous, and series compensated lines.
Page 216 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION The relay internally performs zero-sequence compensation for the protected circuit based on the values entered for the settings, and if Z0/Z1 Magnitude Z0/Z1 Angle configured to do so, zero-sequence compensation for mutual coupling based on the values entered for the settings.
Page 217 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Directional RCA Range: 30 to 90° in steps of 1 Default: 85° The setting specifies the characteristic angle (or maximum torque angle) of the directional supervising function. If the mho shape is applied, the directional function is an extra supervising function, as the dynamic mho characteristic itself is a directional one.
Page 218 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Set this setting at least three times the setting specified in the Current Cutoff Level Settings > Protection > Power System > AC Inputs - Current menu. Zone 1 is sealed in with the current supervision. Voltage Level Range: 0.000 to 5.000 pu in steps of 0.001 Default: 0.000 pu...
Page 219 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 184: Ground distance zone 2 operation logic The following figure shows the ground distance scheme logic for zone 1. Figure 185: Ground distance zone 1 logic The following figure shows the ground distance scheme logic for zone 2. The logic is analogous for zones 3 through 5.
Page 220 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 186: Ground distance zone 2 logic Ground directional supervision A dual (zero-sequence and negative-sequence) memory-polarized directional supervision applied to the ground distance protection elements has been shown to give good directional integrity. However, a reverse double-line-to-ground fault can lead to bad operation of the ground element in a sound phase if the zone reach setting is increased to cover high resistance faults.
Page 221 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 187: Ground directional supervision logic Power swing detect The power swing detect element provides both power swing blocking and out-of-step tripping functions. The element measures the positive-sequence apparent impedance and traces its locus with respect to either two or three user-selectable operating characteristic boundaries.
Page 222 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION the timer specified by the setting times out, latch 1 is set as long as the Delay 1 Pickup impedance stays within the outer characteristic. If afterwards, at any time (given the impedance stays within the outer characteristic), the locus enters the middle characteristic but stays outside the inner characteristic for a period of time defined by the setting, latch 2 is set as long as the...
Page 223 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 189: Effect of blinders on the mho operating characteristic Figure 190: Power swing detect quadrilateral operating characteristic The FlexLogic output operands for the power swing detect element are as follows. Power swing detection operands POWER SWING 50DD.......Asserted when the power swing detection element detects a disturbance other than a power swing.
Page 224 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION POWER SWING BLOCK......Asserted when the power swing detection blocking element operates. POWER SWING INCOMING....Asserted when an unstable power swing is detected (incoming locus). POWER SWING INNER ......Asserted when the positive-sequence impedance is in the inner characteristic.
Page 225 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the power swing detection element. The setting applies to both power swing blocking and out-of-step tripping functions. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for both blocking and tripping functions.
Page 226 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Quadrilateral Forward Outer Range: 0.10 to 500.00 ohms in steps of 0.01 Default: 70.00 ohms This setting specifies the forward reach of the outer quadrilateral characteristic. The angle of this reach impedance is specified by the setting.
Page 227 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Middle Limit Angle Range: 40 to 140° in steps of 1 Default: 90° This setting specifies the middle power swing detect characteristic. It is relevant only for the three-step mode. A typical is close to the average of the outer and inner limit angles. This setting applies to mho shapes only.
Page 228 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Delay 1 Pickup Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.030 seconds All the coordinating timers are related to each other and need to be set to detect the fastest expected power swing and produce out-of-step tripping in a secure manner. Set the timers in relation to the power swing detect characteristics, mode of power swing detect operation, and mode of out-of-step tripping.
Page 229 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Seal-In Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.400 seconds The out-of-step trip FlexLogic operand (POWER SWING TRIP) is sealed-in for the specified period of time. The sealing-in is crucial in the delayed trip mode, as the original trip signal is a very short pulse occurring when the impedance locus leaves the outer characteristic after the out-of-step sequence is completed.
Page 230 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 193: Power swing detect scheme logic, sheet 2 of 3 Figure 194: Power swing detect scheme logic, sheet 3 of 3 Load encroachment The load encroachment element responds to the positive-sequence voltage and current and applies the characteristic shown.
Page 231 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 195: Load encroachment characteristic The element operates if the positive-sequence voltage is above a user-specified level and asserts its output signal that can be used to block selected protection elements, such as distance or phase overcurrent. The following figure shows an effect of the load encroachment characteristics used to block the quadrilateral distance element.
Page 232 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 197: Load encroachment configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the load encroachment element. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for the load encroachment element.
Page 233 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Reset Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.000 seconds This setting specifies a delay for the reset of the load encroachment element between the operate output state and the return to logic 0 after the input passes outside the defined pickup range.
Page 234 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION current supervision prevents misoperation immediately after the fuse fail condition, giving some time for the fuse failure element to take over and block the distance elements permanently. This is of secondary importance for time-delayed zones 2 and up as the fuse failure element has some extra time for guaranteed operation.
Page 235 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Phase distance zone 4 guidelines for stepped distance As a further contribution to remote backup, the reach of this element must be set to account for any infeed at the remote bus. The time delay must coordinate with other time- delayed protection schemes on the next line.
Page 236 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Given the equivalent systems shown in the figure, the angular difference between the Plus zero-sequence or negative-sequence current at the D90 and the fault current can be calculated as follows: Eq. 9 If abs (Θ_0) < abs (Θ_2), then the zero-sequence network is more homogenous (that is, the zero-sequence current better approximates the fault current), and zero-sequence polarizing is selected.
Page 237 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Ground distance zone 3 guidelines for stepped distance This remote back up function must have a reach that is set to account for any infeed at the remote bus, plus the impedance of the longest line that terminates on this remote bus. Similar to the phase fault case, a zone 3 element must be time coordinated with timed clearances on the next section.
Page 238 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 200: Example of series compensated system Assuming 20% security margin, the underreaching zone is set as follows. At the sending bus, one must consider an external fault at F1, as the 5 Ω capacitor contributes to the overreaching effect.
Page 239: Current Elements
Time overcurrent curves The inverse time overcurrent curves used by the time overcurrent elements are the IEEE, IEC, GE Type IAC, and I t standard curve shapes. This allows for simplified coordination with downstream devices. If however, none of these curve shapes is adequate, FlexCurves can be used to customize the inverse time curve characteristics.
Page 240 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION • IEEE Extremely Inverse • IEEE Very Inverse • IEEE Moderately Inverse • IEC Curve A (BS142) • IEC Curve B (BS142) • IEC Curve C (BS142) • IAC Extremely Inverse • IAC Very Inverse •...
Page 241 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Table 13: IEEE inverse time curve constants IEEE curve shape IEEE Extremely Inverse 28.2 0.1217 2.0000 29.1 IEEE Very Inverse 19.61 0.491 2.0000 21.6 IEEE Moderately Inverse 0.0515 0.1140 0.02000 4.85 Table 7-1: IEEE curve trip times (in seconds) Multiplier Current (I / I pickup...
Page 242 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION • = pickup current setting pickup • K, E = constants defined in the table • = reset time in seconds (assuming the energy capacity is 100% and the reset reset mode is “Timed”) •...
Page 243 0.8630 0.8000 –0.4180 0.1947 0.990 IAC Short Inverse 0.0428 0.0609 0.6200 –0.0010 0.0221 0.222 Table 11: GE type IAC curve trip times (in seconds) Multiplier Current (I / I pickup (TDM) 10.0 IAC Extremely Inverse 1.699 0.749 0.303 0.178 0.123 0.093...
Page 244 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Multiplier Current (I / I pickup (TDM) 10.0 2.310 1.499 1.064 0.885 0.784 0.719 0.674 0.640 0.614 0.594 4.621 2.997 2.128 1.770 1.569 1.439 1.348 1.280 1.229 1.188 6.931 4.496 3.192 2.656 2.353 2.158 2.022 1.921 1.843...
Page 245 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS FlexCurves FlexCurves are described in the FlexCurves section later in this chapter. The curve shapes for FlexCurve are derived from the formulae: Eq. 18 Eq. 19 where • = operate time (in seconds) operate •...
Page 246 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 201: Phase time overcurrent voltage restraint characteristic Select the Settings > Protection > Elements > Group 1 > Current > Phase TOC menu item to open the phase time overcurrent configuration window. Figure 202: Phase time overcurrent configuration settings The following settings are available for each phase time overcurrent element.
Page 247 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Pickup Range: 0.000 to 30.000 pu in steps of 0.001 Default: 1.000 pu This setting specifies the phase time overcurrent pickup level in per-unit values. Curve Range: IEEE Mod Inv, IEEE Very Inv, IEEE Ext Inv, IEC Curve A, IEC Curve B, IEC Curve C, IEC Short Inv, IAC Ext Inv, IAC Very Inv, IAC Inverse, IAC Short Inv, I2t, Definite Time, FlexCurve A, FlexCurve B, FlexCurve C, FlexCurve D Default: IEEE Mod Inv...
Page 248 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION The logic for the phase time overcurrent 1 element is shown as follows. The logic is identical for all phase instantaneous overcurrent elements. Figure 203: Phase time overcurrent 1 scheme logic Phase instantaneous overcurrent The phase instantaneous overcurrent element can be used as an instantaneous element with no intentional delay or as a definite time element.
Page 249 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the phase instantaneous overcurrent protection element. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for the phase instantaneous overcurrent protection element.
Page 250 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 205: Phase instantaneous overcurrent 1 scheme logic Phase directional overcurrent The phase directional elements (one for each of phases A, B, and C) determine the phase current flow direction for steady state and fault conditions and can be used to control the operation of the phase overcurrent elements via the Block inputs of these elements.
Page 251 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS This element is intended to apply a block signal to an overcurrent element to prevent an operation when current is flowing in a particular direction. The direction of current flow is determined by measuring the phase angle between the current from the phase CTs and the line-line voltage from the VTs, based on the 90°...
Page 252 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 207: Phase directional overcurrent configuration settings The following settings are available for each phase directional overcurrent element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the phase directional overcurrent protection element. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1)
Page 253 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Block When Voltage Memory Expires Range: Yes, No Default: No This setting is used to select the required operation upon expiration of voltage memory. When set to “Yes,” the directional element blocks the operation of any phase overcurrent element under directional control, when voltage memory expires.
Page 254 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Select the Settings > Protection > Elements > Group 1 > Current > Neutral TOC menu to open the neutral time overcurrent configuration window. Figure 209: Neutral time overcurrent configuration settings The following settings are available for each neutral time overcurrent element. Function Range: Enabled, Disabled Default: Disabled...
Page 255 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Reset Range: Instantaneous, Timed Default: Instantaneous The “Instantaneous” reset method is intended for applications with other relays, such as most static relays, which set the energy capacity directly to zero when the current falls below the reset threshold.
Page 256 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION The positive-sequence restraint must be considered when testing for pickup accuracy and response time (multiple of pickup). The operating quantity depends on how test currents are injected into the relay. For single-phase injection, the operating quantity is Eq.
Page 257 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Block Range: any FlexLogic operand or shared operand Default: Off Assertion of the operand assigned to this setting blocks operation of the neutral instantaneous overcurrent element. Events Range: Enabled, Disabled Plus Plus Default: varies with UR -series model;...
Page 258 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION The positive-sequence restraint is removed for low currents. If the positive-sequence current is below 0.8 pu, the restraint is removed by changing the constant K to zero. This facilitates better response to high-resistance faults when the unbalance is very small and there is no danger of excessive CT errors as the current is low.
Page 259 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 213: Neutral directional voltage polarized characteristics The neutral directional overcurrent element incorporates a current reversal logic. If the reverse direction is indicated for at least 1.25 of a power system cycle, the prospective forward indication is delayed by 1.5 of a power system cycle.
Page 260 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 214: Neutral directional overcurrent configuration settings The following settings are available for each neutral directional overcurrent element. Function Default: Enabled, Disabled Default: Disabled This setting enables and disables the neutral directional overcurrent protection element. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1)
Page 261 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS For a choice of current polarizing, it is recommended that the polarizing signal be analyzed to ensure that a known direction is maintained irrespective of the fault location. For example, if using an autotransformer neutral current as a polarizing source, ensure that a reversal of the ground current does not occur for a high-side fault.
Page 262 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Forward ECA Range: –90 to 90° in steps of 1 Default: –70° This setting defines the characteristic angle (ECA) for the forward direction in the “Voltage” polarizing mode. The “Current” polarizing mode uses a fixed ECA of 0°. The ECA in the reverse direction is the angle set for the forward direction shifted by 180°.
Page 263 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 215: Neutral directional overcurrent 1 scheme logic Ground time overcurrent This element can provide a required time-delay operating characteristic versus the applied current or be used as a simple definite time element. The ground current input value is the quantity measured by the ground input CT and is the fundamental phasor or RMS magnitude.
Page 264 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 216: Ground time overcurrent configuration settings The following settings are available for each ground time overcurrent element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the ground time overcurrent protection element. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1)
Page 265 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Reset Range: Instantaneous, Timed Default: Instantaneous The “Instantaneous” reset method is intended for applications with other relays, such as most static relays, which set the energy capacity directly to zero when the current falls below the reset threshold.
Page 266 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 218: Ground instantaneous overcurrent configuration settings The following settings are available for each ground instantaneous overcurrent element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the ground instantaneous overcurrent protection element.
Page 267 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Events Range: Enabled, Disabled Plus Plus Default: varies with UR -series model; see the EnerVista UR Setup software This setting enables and disables the logging of ground instantaneous overcurrent events in the sequence of events recorder. The figure shows the logic for the ground instantaneous overcurrent 1 element.
Page 268 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for the negative-sequence time overcurrent protection element. Pickup Range: 0.000 to 30.000 pu in steps of 0.001 Default: 1.000 pu This setting specifies the neutral time overcurrent pickup level in per-unit values.
Page 269 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 221: Negative-sequence time overcurrent scheme logic Negative-sequence instantaneous overcurrent The negative-sequence instantaneous overcurrent element can be used as an instantaneous function with no intentional delay or as a definite time function. The element responds to the negative-sequence current fundamental frequency phasor magnitude (calculated from the phase currents) and applies a positive-sequence restraint for better performance: a small portion (12.5%) of the positive-sequence current magnitude is subtracted from the negative-sequence current magnitude when forming...
Page 270 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the negative-sequence instantaneous overcurrent protection element. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for the negative-sequence instantaneous overcurrent protection element.
Page 271 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Negative-sequence directional overcurrent There are two negative-sequence directional overcurrent protection elements available. The element provides both forward and reverse fault direction indications through its output operands REV, respectively. The output NEG SEQ DIR OC1 FWD NEG SEQ DIR OC1 operand is asserted if the magnitude of the operating current is above a pickup level (overcurrent unit) and the fault direction is seen as forward or reverse, respectively...
Page 272 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION validated, neither forward nor reverse indication is given. In addition, the negative- sequence current (or zero-sequence current) must be greater than the Current Cutoff Level setting value specified in the Protection > Power System > AC Inputs – Current menu. The following figure explains the usage of the voltage polarized directional unit of the element.
Page 273 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 225: Negative-sequence directional overcurrent configuration settings The following settings are available for each negative-sequence directional overcurrent element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the negative-sequence directional overcurrent protection element. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1)
Page 274 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Pos Seq Restraint Range: 0.000 to 0.500 in steps of 0.001 Default: 0.063 This setting controls the amount of the positive-sequence restraint. Set it to zero to remove the restraint. Set it to a higher value if large system unbalances or poor CT performance are expected.
Page 275: Voltage Elements
CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 226: Negative-sequence directional overcurrent scheme logic Voltage elements The voltage protection elements can be used for a variety of applications, such as undervoltage protection, permissive functions, and source transfer schemes. For voltage sensitive loads, such as induction motors, a drop in voltage increases the drawn current that can cause dangerous overheating in the motor.
Page 276 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION V is the secondary voltage applied to the relay is the pickup level pickup Figure 227: Inverse time undervoltage curves At 0% of pickup, the operating time is equivalent to the undervoltage delay setting. NOTE: Phase undervoltage The phase undervoltage element can be used to give a required time delay operating...
Page 277 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Signal Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for the phase undervoltage protection element. Mode Range: Phase to Ground, Phase to Phase Default: Phase to Ground This setting selects the operating mode.
Page 278 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION PHASE UV1 OP..........Asserted when at least one phase of the phase undervoltage 1 element operates. PHASE UV1 OP A ........Asserted when phase A of the phase undervoltage 1 element operates. PHASE UV1 OP B ........Asserted when phase B of the phase undervoltage 1 element operates.
Page 279 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 230: Phase overvoltage configuration settings The following settings are available for each phase overvoltage element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the phase overvoltage protection element. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for the phase overvoltage protection element.
Page 280 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 231: Phase overvoltage logic Neutral overvoltage There are three neutral overvoltage elements available. The neutral overvoltage element can be used to detect asymmetrical system voltage condition due to a ground fault or to the loss of one or two phases of the source.
Page 281 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for the neutral overvoltage protection element. Pickup Range: 0.000 to 1.250 pu in steps of 0.001 Default: 0.300 pu This setting specifies the neutral overvoltage pickup level in per-unit values.
Page 282 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Negative-sequence overvoltage The negative-sequence overvoltage element can be used to detect loss of one or two phases of the source, a reversed phase sequence of voltage, or a non-symmetrical system voltage condition. Select the Settings > Protection > Elements > Group 1 > Voltage > Negative Sequence OV menu to open the negative-sequence overvoltage configuration window.
Page 283 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of negative-sequence overvoltage events in the sequence of events recorder. The figure shows the logic for the negative-sequence overvoltage 1 element. The logic is similar for all negative-sequence overvoltage elements.
Page 284 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the signal source for the auxiliary undervoltage protection element. Pickup Range: 0.000 to 3.000 pu in steps of 0.001 Default: 0.700 pu This setting specifies the auxiliary undervoltage pickup level in per-unit values.
Page 285 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Auxiliary overvoltage This element is intended for monitoring overvoltage conditions of the auxiliary voltage. A typical application for this element is monitoring the zero-sequence voltage (3V_0) supplied from an open-corner-delta VT connection. The nominal secondary voltage of the auxiliary voltage channel entered in the setting is the per-unit base Auxiliary VT Secondary...
Page 286: Breaker Failure
GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of auxiliary overvoltage events in the sequence of events recorder. The figure shows the logic for the auxiliary overvoltage element. The logic is identical for all auxiliary overvoltage elements.
Page 287 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 241: Breaker failure current supervision reset time Breaker failure initiation stage A FlexLogic operand representing the protection trip signal initially sent to the breaker must be selected to initiate the scheme, except if this is already programmed as a trip output (the protection trip signal does not include other breaker commands that are not indicative of a fault in the protected zone).
Page 288 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Timer 1 logic (early path) is supervised by a fast-operating breaker auxiliary contact. If the breaker is still closed (as indicated by the auxiliary contact) and fault current is detected after the delay interval, an output is issued. Operation of the breaker auxiliary switch indicates that the breaker has mechanically operated.
Page 289 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 242: Breaker failure configuration settings The following settings are available for each breaker failure element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the breaker failure protection element. Mode Range: 1-Pole, 3-Pole Default: 1-Pole This setting selects the breaker failure operating mode: single-pole or three-pole.
Page 290 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Use Seal-In Range: Yes, No Default: Yes If set to “Yes,” the breaker failure element is sealed-in only if current flowing through the breaker is above the supervision pickup level. Three Pole Initiate Range: any FlexLogic operand or shared operand Default: Off This setting selects the operand that initiates three-pole tripping of the breaker when asserted.
Page 291 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Plus In the UR -series devices, which use a Fourier transform, the calculated current magnitude ramps-down to zero one power frequency cycle after the current is interrupted, and this lag needs to be included in the overall margin duration, as it occurs after current interruption.
Page 292 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Neutral Current High-Set Pickup Range: 0.001 to 30.000 pu in steps of 0.001 Default: 1.050 pu This setting specifies the neutral current output supervision level. Generally, this setting needs to detect the lowest expected fault current on the protected breaker, before a breaker opening resistor is inserted.
Page 293 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Breaker Position 1 Phase B Range: any FlexLogic operand or shared operand Default: Off This setting selects the operand to represent the protected breaker early-type auxiliary switch contact on pole B. This contact is normally a non-multiplied form-A contact. The contact can even be adjusted to have the shortest possible operating time.
Page 294 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 243: Breaker failure single-pole logic, sheet 1 of 3 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 295 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 244: Breaker failure single-pole logic, sheet 2 of 3 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 296 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 245: Breaker failure single-pole logic, sheet 3 of 3 Figure 246: Breaker failure three-pole logic, sheet 1 of 3 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 297: Wattmetric Zero-Sequence Directional Ground Fault
CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 247: Breaker failure three-pole logic, sheet 2 of 3 Figure 248: Breaker failure three-pole logic, sheet 3 of 3 Wattmetric zero-sequence directional ground fault The wattmetric zero-sequence directional element responds to power derived from zero- sequence voltage and current in a direction specified by the element characteristic angle.
Page 298 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 249: Wattmetric ground fault configuration window The following settings are available for each wattmetric zero-sequence directional ground fault element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the wattmetric zero-sequence directional ground fault protection element.
Page 299 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Current Range: Calculated IN, Measured IG Default: Calculated IN The wattmetric zero-sequence directional ground fault element responds to the neutral current (that is, three times zero-sequence current), either calculated internally from the phase currents or supplied externally via the ground CT input from more accurate sources, such as the core balanced CT.
Page 300 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 250: Wattmetric characteristic angle response Power Pickup Delay Range: 0.00 to 600.00 seconds in steps of 0.01 Default: 0.20 seconds This setting specifies a definite time delay before the inverse time characteristic is activated.
Page 301: Control Elements
CHAPTER 7: PROTECTION CONTROL ELEMENTS where m is a multiplier defined by the multiplier setting is the pickup setting is the operating power at the time. This timer starts after the definite time timer expires. The four FlexCurves allow for custom user-programmable time characteristics. When working with FlexCurves, the element uses the operate to pickup ratio, and the multiplier setting is not applied: Eq.
Page 302: Pilot-Aided Schemes
CONTROL ELEMENTS CHAPTER 7: PROTECTION Pilot-aided schemes This section contains settings for selecting and configuring protection signaling schemes. All schemes are available for single-pole tripping applications and can be used with single- bit, two-bit, or four-bit communications channels. Choices of communications channels include remote inputs, remote outputs, and telecommunications interfaces.
Page 303 CHAPTER 7: PROTECTION CONTROL ELEMENTS Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the direct under-reaching transfer trip (DUTT) scheme. Seal-In Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.000 seconds The DUTT OP FlexLogic operand is produced according to the scheme logic. A seal-in time delay is applied to this operand for coping with noisy communication channels, such as a power line carrier.
Page 304 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 253: DUTT logic Permissive under-reaching transfer trip The permissive under-reaching transfer trip (PUTT) scheme uses an under-reaching zone 1 distance element to key the transfer trip signal to the remote terminals where they are supervised by an over-reaching zone 2 distance element.
Page 305 CHAPTER 7: PROTECTION CONTROL ELEMENTS The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the permissive under-reaching transfer trip (PUTT) scheme. RX Pickup Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.000 seconds This setting enables the relay to cope with spurious receive signals.
Page 306 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 255: PUTT logic Permissive over-reaching transfer trip The permissive over-reaching transfer trip (POTT) scheme is for two-terminal line applications. This scheme uses an over-reaching zone 2 distance element to compare the direction to a fault at both terminals of the line. Ground directional overcurrent functions available in the relay can be used in conjunction with the zone 2 distance element to key the scheme and initiate its operation.
Page 307 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 256: POTT scheme configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the permissive over-reaching transfer trip (POTT) scheme. Permissive Echo Range: Enabled, Custom, Disabled Default: Disabled If this setting is “Enabled,”...
Page 308 CONTROL ELEMENTS CHAPTER 7: PROTECTION Transient Block Pickup Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.020 seconds This setting defines a transient blocking mechanism embedded in the POTT scheme for coping with the exposure of a ground directional overcurrent function (if used) to current reversal conditions.
Page 309 CHAPTER 7: PROTECTION CONTROL ELEMENTS Line End Open Pickup Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.050 seconds This setting specifies the pickup value for validation of the line end open conditions as detected by the line pickup logic through the FlexLogic operand.
Page 310 CONTROL ELEMENTS CHAPTER 7: PROTECTION Events Range: Enabled, Disabled Default: Enabled This setting enables and disables the logging of permissive over-reaching transfer trip (POTT) scheme events in the sequence of events recorder. The figure shows the POTT scheme logic. Figure 257: POTT logic Hybrid permissive over-reaching transfer trip The hybrid permissive over-reaching transfer trip (hybrid POTT) scheme uses an overreaching zone 2 distance element to compare the direction to a fault at all terminals...
Page 311 CHAPTER 7: PROTECTION CONTROL ELEMENTS For proper operation, the zone 2 and 4 phase and ground distance elements must be enabled and configured according to the principles of distance relaying. The line pickup element needs to be enabled and configured to detect line-end-open or weak-infeed and undervoltage conditions.
Page 312 CONTROL ELEMENTS CHAPTER 7: PROTECTION Permissive Echo Range: Enabled, Custom, Disabled Default: Disabled If this setting is “Enabled,” the hybrid POTT scheme sends a permissive echo signal to the remote ends using pre-programmed logic (see the logic diagram). If set to “Custom,” the echo signal is sent if the condition selected by the setting is satisfied.
Page 313 CHAPTER 7: PROTECTION CONTROL ELEMENTS Echo Duration Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.100 seconds This setting specifies the guaranteed and exact duration of the echo pulse. The duration is not dependent on the duration and shape of received RX signals. This setting enables the relay to avoid a permanent lock-up of the transmit-receive loop.
Page 314 CONTROL ELEMENTS CHAPTER 7: PROTECTION sequence directional or neutral directional overcurrent element. Both these elements have separate forward and reverse output operands. Use the reverse indication (NEG SEQ DIR OC1 REV NEUTRAL DIR OC1 REV). Coordinate the selected protection element (or elements in combination) with the selection of the setting.
Page 315 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 259: Hybrid POTT logic Directional comparison blocking The directional comparison blocking scheme compares the direction to a fault at all terminals of the line. Unlike the permissive schemes, the absence of a blocking signal permits operation of the scheme.
Page 316 CONTROL ELEMENTS CHAPTER 7: PROTECTION reverse-looking zone 4 distance element identifies reverse faults. The ground directional overcurrent functions can be used in conjunction with the zone 4 distance element for better time and sensitivity coordination. For proper operation, the zone 2 and 4 phase and ground distance elements must be enabled and configured according to the principles of distance relaying.
Page 317 CHAPTER 7: PROTECTION CONTROL ELEMENTS RX Coordination Pickup Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 0.010 seconds This setting specifies a time delay for the forward-looking protection elements used by the scheme for coordination with the blocking response from the remote ends. This setting is to include both the response time of the protection elements used to establish a blocking signal and the total transmission time of that signal including the relay communications equipment interfacing and the communications channel itself.
Page 318 CONTROL ELEMENTS CHAPTER 7: PROTECTION Ground Directional OC Forward Range: any FlexLogic operand Default: OFF This setting selects the FlexLogic operand (if any) of a protection element used in addition to zone 2 for identifying faults on the protected line, and thus, for initiating operation of the scheme.
Page 319 CHAPTER 7: PROTECTION CONTROL ELEMENTS RX1, RX2, RX3, RX4 Range: any FlexLogic operand Default: OFF These settings allow the user to select the FlexLogic operands that represent the receive signals for the directional comparison blocking scheme. Typically input contacts interfacing with a signaling system are used as follows: –...
Page 320 CONTROL ELEMENTS CHAPTER 7: PROTECTION The directional comparison unblocking scheme typically uses an over-reaching zone 2 distance element to compare the direction to a fault at all terminals of the line. Ground directional overcurrent functions available in the device can be used in conjunction with the zone 2 distance element to key the scheme and initiate its operation.
Page 321 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 262: Directional comparison unblocking scheme configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the directional comparison unblocking scheme. Block Range: any FlexLogic operand Default: OFF This setting allows the user to assign any FlexLogic operand to block the directional comparison unblocking scheme.
Page 322 CONTROL ELEMENTS CHAPTER 7: PROTECTION Ground Directional OC Forward Range: any FlexLogic operand Default: OFF This setting selects the FlexLogic operand (if any) of a protection element used in addition to zone 2 for identifying faults on the protected line, and thus, for keying the communication channels and initiating operation of the scheme (both through the transient blocking logic).
Page 323 CHAPTER 7: PROTECTION CONTROL ELEMENTS However, if distance zone 1 picks up during the transient blocking condition, the blocking Plus action is removed. This allows the D90 to cope with evolving faults when an external fault is followed by an internal fault. Without the zone 1 feedback, the trip is delayed unnecessarily.
Page 324 CONTROL ELEMENTS CHAPTER 7: PROTECTION set relatively short, but long enough to ride through the transition period of loss-of- guard with the receipt of a permissive signal that occurs with a normal trip. Typical settings are from 4 to 32 ms. For most cases, a value of 8 ms can be used. The tripping or unblocking window for loss-of-guard without permission is the difference between the timers specified by the Loss of Guard Trip Window...
Page 325 CHAPTER 7: PROTECTION CONTROL ELEMENTS RX1, RX2, RX3, RX4 Range: any FlexLogic operand Default: OFF These settings select FlexLogic operands to represent the permission receive signals for the scheme. Contact inputs interfacing with a signaling system typically are used. These settings must be used in conjunction with the loss-of-guard signals, otherwise the scheme does not unblock and thus fails to operate.
Page 326 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 263: Directional comparison unblocking scheme logic, sheet 1 of 2 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 327 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 264: Directional comparison unblocking scheme logic, sheet 2 of 2 Pilot-aided scheme application guidelines Plus This section provides guidelines for implementing pilot-aided schemes with the D90 Direct underreaching transfer trip (DUTT) application guidelines The direct underreaching transfer trip (DUTT) scheme uses an under-reaching zone 1 distance element to key a transfer trip signal to the remote end or ends, where on receipt, the DUTT pilot scheme operates without any additional supervision.
Page 328 CONTROL ELEMENTS CHAPTER 7: PROTECTION The scheme generates an output operand (PUTT TX) that is used to transmit the signal to the remote end. Choices of communications channel include remote inputs and outputs and telecommunications interfaces. When used with telecommunications facilities, assign the output operand to operate an output contact connected to key the transmitter at the interface.
Page 329 CHAPTER 7: PROTECTION CONTROL ELEMENTS POTT scheme is to recognize that a permissive signal has been received and then allow the time specified by the setting for the local forward looking Transient Block Pickup Delay directional element to pick up. The POTT scheme generates an output operand (POTT TX) that is used to transmit the signal...
Page 330 CONTROL ELEMENTS CHAPTER 7: PROTECTION Directional comparison blocking application guidelines The directional comparison blocking scheme typically compares the direction to a fault at both ends of the line. Unlike the permissive schemes, the absence of a blocking signal permits operation of the scheme. Consequently, the scheme is biased toward dependability and requires an “on/off”...
Page 331 CHAPTER 7: PROTECTION CONTROL ELEMENTS communications equipment fails. This loss-of-guard output connects to a contact input of Plus the D90 . The power line carrier should also provide an output contact when the Plus permissive frequency is received. Wire this output to any other contact input of the D90 The directional comparison unblocking scheme allows a window of opportunity for fast tripping of the breaker if the permissive signal gets attenuated by the fault to a level less than the receiver's threshold.
Page 332 CONTROL ELEMENTS CHAPTER 7: PROTECTION The loss-of-guard operation picks up if all of the following conditions hold: • The directional comparison unblocking scheme is enabled and not blocked (that is, the scheme is active) • Any loss-of-guard signal is received without its associated RX signal •...
Page 333: Setting Group Control
CHAPTER 7: PROTECTION CONTROL ELEMENTS C, and output operands are hard-wired DCUB TRIP DCUB TRIP DCUB TRIP DCUB TRIP 3P to the trip output scheme. As such, if the trip output or breaker control operands (if the breaker control function is used) are used for tripping, the scheme fully operational. The permissive key carrier signals DCUB TX1 through DCUB TX4 must still be assigned to the Plus tripping or operating logic, and to output contacts as per the usual D90...
Page 334: Trip Output
CONTROL ELEMENTS CHAPTER 7: PROTECTION takes priority over the lower-numbered groups. There is no activation setting group 1 (the default active group) since group 1 automatically becomes active when there is no other group active. Group 1 Name, Group 2 Name, Group 3 Name, Group 4 Name, Group 5 Name, Group 6 Name Range: up to 16 alphanumeric characters Default: empty...
Page 335 CHAPTER 7: PROTECTION CONTROL ELEMENTS Single-pole operation This element must be used in single-pole operation applications. NOTE: The trip output element performs the following applications for single-pole operations: • Determines if a single-pole operation is performed • Collects inputs to initiate three-pole tripping, the autorecloser, and breaker failure elements •...
Page 336 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 267: Trip output configuration settings The following settings are available. Trip Mode Range: Disabled, 3 Pole Only, 3 Pole & 1 Pole Default: Disabled This setting selects the required mode of operation. If selected to “3 Pole Only,” outputs for all three phases are always set simultaneously.
Page 337 CHAPTER 7: PROTECTION CONTROL ELEMENTS operand is asserted by the autorecloser 1.5 cycles after single-pole AR FORCE 3-P TRIP reclosing is initiated. This operand calls for a three-pole trip if any protection element configured under which this setting remains picked-up. The open pole detector provides blocking inputs to distance elements;...
Page 338 CONTROL ELEMENTS CHAPTER 7: PROTECTION pickup delay, and a two-cycle dropout delay. Use this setting only in single-pole tripping applications when evolving faults are of importance and slightly delayed operation on evolving faults can be traded for enhanced accuracy of single-pole tripping. Trip Delay on Evolving Faults Range: 0 to 65.535 seconds in steps of 0.001 Default: 0.000 seconds...
Page 339 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 268: Trip output logic, sheet 1 of 2 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 340: Flexmatrix
CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 269: Trip output logic, sheet 2 of 2 FlexMatrix The FlexMatrix allows up to 16 inputs to be aggregated and conditioned for tripping or auxiliary functions. Up to eight output signals can be derived from the input signals. Outputs can be configured for latching (lockout) and can also have a programmable pickup and dropout delay.
Page 341 CHAPTER 7: PROTECTION CONTROL ELEMENTS FlexMatrix inputs Select the Settings > Protection > Control > FlexMatrix > FlexMatrix Inputs menu to access the FlexMatrix input settings. Figure 270: FlexMatrix input configuration settings The following setting is available for each of the 16 FlexMatrix inputs. Input 1, Input 2,..., Input 16 Range: any FlexLogic operand or shared operand Default: OFF...
Page 342 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 271: FlexMatrix configuration settings The following settings are available for each of the eight FlexMatrix elements. Function Range: Enabled, Disabled Default: Disabled This setting enables or disables the FlexMatrix element. Name Range: 12 alphanumeric characters Default: Flexmat 1 This setting specifies the name associated with a particular FlexMatrix element.
Page 343: Vt Fuse Failure
CHAPTER 7: PROTECTION CONTROL ELEMENTS Dropout Delay Range: 0.000 to 60.000 seconds in steps of 0.001 Default: 0.000 seconds This setting specifies the delay by which to extend the FlexMatrix dropout. Latching Range: Enabled, Disabled Default: Disabled When this setting is enabled, the FlexMatrix output is latched until the reset input is asserted.
Page 344 CONTROL ELEMENTS CHAPTER 7: PROTECTION The VT fuse failure detector can be used to raise an alarm or block elements that can operate incorrectly for a full or partial loss of AC potential caused by one or more blown fuses. Some elements that can be blocked (via the Block setting) include voltage restrained overcurrent and directional current.
Page 345: Open Pole Detector
CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 274: VT fuse failure logic Open pole detector The open pole detector identifies an open pole of the line circuit breaker. It monitors the breaker’s auxiliary contacts, current in the circuit, and voltage (optional) on the line. The scheme generates output operands used to block the phase selector and some specific protection elements, thus preventing maloperation during the dead time of a single pole autoreclose cycle or any other open pole conditions.
Page 346 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 275: Open pole detector configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the open pole detector feature. Block Range: any FlexLogic operand or shared operand Default: OFF Assertion of the operand assigned to this setting blocks operation of the open pole detector element.
Page 347 CHAPTER 7: PROTECTION CONTROL ELEMENTS Open Pole Remote Current Pickup Range: 0.000 to 30.000 pu in steps of 0.001 Default: 0.050 pu This setting specifies the pickup level for the remote-end current estimated by the relay as the local current compensated by the calculated charging current. The latter is calculated based on the local voltages and the capacitive reactances of the line.
Page 348: Autoreclose
CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 277: Open pole detector logic, sheet 2 of 2 Autoreclose The autoreclose scheme is for use on transmission lines with circuit breakers operated in both the single-pole and three-pole modes, in one or two breaker arrangements. The autoreclose scheme provides four programs with different operating cycles, depending on the fault type.
Page 349 CHAPTER 7: PROTECTION CONTROL ELEMENTS Autoreclose programs The autorecloser provides four programs that can cause from one to four reclose attempts (shots). After the first shot, all subsequent reclosings are always three-pole. If the maximum number of shots selected is 1 (only one reclose attempt) and the fault is persistent, after the first reclose the scheme goes to lockout upon another initiate signal.
Page 350 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 278: Autoreclose enable logic Figure 279: Autoreclose initiate logic A reclose initiate signal sends the scheme into the reclose-in-progress (RIP) state and asserts the operand. Once the breaker has opened, the scheme is latched into the AR RIP reclose-in-progress state and resets only when an (autoreclose breaker 1) or...
Page 351 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 280: Autoreclose reclose-in-progress logic After entering the reclose-in-progress state, a close command is issued after the dead time delay. The dead time for the initial reclose operation is determined by either the 1-P Dead Time 3-P Dead Time 1 , or...
Page 352 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 281: Autoreclose breaker close logic Figure 282: Autoreclose close breaker 1 or 2 logic Figure 283: Autoreclose termination logic Multi-shot operation setting defines the number of reclose attempts. After each Maximum Number of Shots reclose, the shot counter increments.
Page 353 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 284: Autoreclose shot counter logic Autoreclose pause input The autoreclose pause input offers the possibility of freezing the autoreclose cycle until the pause signal disappears. This can be done when a trip occurs and simultaneously or previously, some conditions are detected such as out-of step or loss of guard frequency, or a remote transfer trip signal is received.
Page 354 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 286: Autoreclose transfer logic When the 1-2 reclosing sequence is selected and breaker 1 is blocked (the AR BKR1 BLK operand is set), the reclose signal can be transferred direct to breaker 2 when the Transfer setting is “Yes.”...
Page 355 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 287: Autoreclose failure-to-close logic Figure 288: Typical autoreclose sequence PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 356 CONTROL ELEMENTS CHAPTER 7: PROTECTION Breaker block A reclose command to a breaker is inhibited if it receives a user-defined block input or if it is out-of-service. A logic circuit also is provided that inhibits a breaker reclose if that breaker was open in advance of a reclose initiate input to the recloser.
Page 357 CHAPTER 7: PROTECTION CONTROL ELEMENTS Autoreclose lockout When a reclose sequence is started by an initiate signal, the autoreclose scheme moves into the reclose-in-progress state and starts the incomplete sequence timer. The setting of this timer determines the maximum time interval allowed for a single reclose shot. If a close breaker 1 or 2 signal is not present before this time expires, the scheme enters the lockout state.
Page 358 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 291: Autoreclose lockout logic PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 359 CHAPTER 7: PROTECTION CONTROL ELEMENTS Zone 1 extension in the autoreclose scheme Two approaches are available for implementation of zone 1 extension. The first method is to operate normally from an under-reaching zone and use an overreaching distance zone when reclosing the line with the other line end open. This method can be programmed via the line pickup scheme.
Page 360 CONTROL ELEMENTS CHAPTER 7: PROTECTION • Breaker 2 issues a manual close signal, sequence 1 is not selected, and breaker 1 is either open or out-of-service Alternately, a user-defined setting is available to generate this signal. Figure 294: Autoreclose manual close logic Terminal closed The close logic uses the status of each breaker to determine whether the terminal is closed.
Page 361 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 296: Autoreclose closing logic, sheet 2 of 2 Terminal three-pole open The autoreclose scheme employs dedicated logic to determine if all three poles are opened at the local terminal. This signal is used in the preceding logic. For single-breaker operation, the breaker status is sufficient to derive this signal.
Page 362 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 297: Terminal three-pole open logic Terminal one-pole open The autoreclose scheme also has dedicated logic to determine if one pole is opened at the local terminal. For single-breaker operation, the BREAKER 1 ONE P OPEN BREAKER 2 ONE P operand is used to derive this signal.
Page 363 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 298: Terminal one-pole open logic Autoreclose settings Select the Settings > Protection > Control > Autoreclose menu to access the autoreclose settings. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 364 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 299: Autoreclose settings window The following settings are available. Function Range: Disabled, Enabled Default: Disabled This setting enables and disables the autoreclose scheme. Mode Range: 1 & 3 Pole, 1 Pole, 3 Pole-A, 3 Pole-B Default: 1 &...
Page 365 CHAPTER 7: PROTECTION CONTROL ELEMENTS Select Time Range: 1.0 to 30.0 seconds in steps of 0.1 Default: 5 seconds This setting specifies the maximum permissible time from selection of autoreclose and a control action. Maximum Number of Shots Range: 1, 2, 3, 4 Default: 2 This setting specifies the number of reclosures attempted before reclosure goes to lockout when the fault is permanent.
Page 366 CONTROL ELEMENTS CHAPTER 7: PROTECTION 3-Pole TD Initiate Range: any FlexLogic operand or shared operand Default: Off This setting selects an operand used to initiate three-pole autoreclosure. The second timer ( ) can be used for a time-delay autoreclosure. 3-Pole Dead Time 2 Multi-Phase Fault Range: any FlexLogic operand or shared operand Default: Off...
Page 367 CHAPTER 7: PROTECTION CONTROL ELEMENTS Extend Dead Time 1 Range: any FlexLogic operand or shared operand Default: Off This setting selects an operand to adapt the duration of the dead time for the first shot to the possibility of non-simultaneous tripping at the two line ends. Typically this is the operand set when the communication channel is out-of-service.
Page 368 CONTROL ELEMENTS CHAPTER 7: PROTECTION Incomplete Sequence Time Range: 0 to 655.35 seconds in steps of 0.01 Range: 5.00 seconds This setting specifies the maximum time interval allowed for a single reclose shot. It is started whenever a reclosure is initiated and is active until the CLOSE BKR1 CLOSE BKR2 signal is sent.
Page 369 CHAPTER 7: PROTECTION CONTROL ELEMENTS Breaker 2 Failure Option Range: Continue, Lockout Default: Continue This setting establishes how the scheme performs when the breaker closing sequence is “2-1” and breaker 2 has failed to close. When set to “Continue,” the closing command is transferred to breaker 1, which continues the reclosing cycle until successful (the scheme resets) or unsuccessful (the scheme goes to lockout).
Page 370 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 300: Final autoreclose signal flow logic Front panel status and control If the autoreclose function is enabled, a status indicator appears on the screen. Table 20: Autoreclose front panel indications Indication FlexLogic operand Autoreclose ON AR ENABLED Autoreclose OFF AR DISABLED...
Page 371: Underfrequency
CHAPTER 7: PROTECTION CONTROL ELEMENTS Autoreclose control is available at the top-level screen by pressing the AR pushbutton. If local control is not asserted for autoreclose, then the AR pushbutton is grey and inoperable. The local control status of a device is obtained from the autoreclose control logic.
Page 372 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 303: Underfrequency configuration settings The following settings are available for each underfrequency element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the underfrequency function. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the source for the signal to be measured.
Page 373: Overfrequency
CHAPTER 7: PROTECTION CONTROL ELEMENTS Block Range: any FlexLogic operand or shared operand Default: OFF Assertion of the operand assigned to this setting blocks operation of the underfrequency element. Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of underfrequency events in the sequence of events recorder.
Page 374 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 305: Overfrequency configuration settings The following settings are available for each overfrequency element. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the overfrequency function. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: LINE (SRC 1) This setting selects the source for the signal to be measured.
Page 375: Breaker Configuration
CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 306: Overfrequency logic Breaker configuration The breaker configuration element contains the auxiliary logic for status and serves as the interface for opening and closing of the breaker from protection and automation functions. The logic also permits a manual substitution of the position indication. Select the Settings >...
Page 376 CONTROL ELEMENTS CHAPTER 7: PROTECTION Long Name Range: 20 alphanumeric characters Default: Breaker 1 This setting identifies the primary device for control confirmations on the front panel interface and in the event record. Short Name Range: up to 6 alphanumeric characters Default: BKR1 This setting identifies the primary device pushbuttons and indications on the front panel interface.
Page 377 CHAPTER 7: PROTECTION CONTROL ELEMENTS Block Close Command Range: any FlexLogic operand or shared operand Default: Off This setting selects an operand that prevents closing of the breaker. This setting can be used for select-before-operate functionality or to block operation from a panel switch or from SCADA.
Page 378 CONTROL ELEMENTS CHAPTER 7: PROTECTION Phase C Opened Status Range: any FlexLogic operand or shared operand Default: Off The operand selected by this setting is used to derive the phase B breaker position indication from a normally-closed (52b) status input. If unavailable, the closed status input can be inverted to provide this signal.
Page 379 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 308: Breaker configuration logic, sheet 1 of 4 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 380 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 309: Breaker configuration logic, sheet 2 of 4 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 381 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 310: Breaker configuration logic, sheet 3 of 4 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 382: Breaker Flashover
CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 311: Breaker configuration logic, sheet 4 of 4 Breaker flashover The detection of breaker flashover is based on the following condition: Breaker open Voltage drop measured from either side of the breaker during the flashover period Voltage difference drop Measured flashover current through the breaker Furthermore, the breaker flashover scheme is applicable for cases where either one or two...
Page 383 CHAPTER 7: PROTECTION CONTROL ELEMENTS Breaker flashover settings Select the Settings > Protection > Control > Breaker Flashover menu to open the breaker flashover configuration window. Figure 312: Breaker flashover configuration settings The following settings are available for each breaker flashover element. Function Range: Enabled, Disabled Default: Disabled...
Page 384 CONTROL ELEMENTS CHAPTER 7: PROTECTION Voltage Pickup Range: 0.000 to 1.500 pu in steps of 0.001 Default: 0.850 pu This setting specifies a pickup level for the phase voltages from both sides of the breaker. If six VTs are available, opening the breaker leads to two possible combinations – live voltages from only one side of the breaker, or live voltages from both sides of the breaker.
Page 385 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 313: Breaker flashover logic, sheet 1 of 2 Figure 314: Breaker flashover logic, sheet 2 of 2 Three VT breaker flashover application When only one set of VTs is available across the breaker, set the setting to “None.”...
Page 386 CONTROL ELEMENTS CHAPTER 7: PROTECTION indicating the breaker status is off), and no flashover current is flowing. A contact showing the breaker status must be provided to the relay. The voltage difference is not considered as a condition for open breaker in this part of the logic. Voltages must be present prior to flashover conditions.
Page 387: Digital Counters
CHAPTER 7: PROTECTION CONTROL ELEMENTS Consider the configuration shown. Figure 316: Breaker flashover application example The source 1 (SRC1) phase currents are CTs and phase voltages are bus VTs. The source 2 (SRC2) phase voltages are line VTs. Contact input 1 is set as the breaker 52a contact (optional).
Page 388 CONTROL ELEMENTS CHAPTER 7: PROTECTION Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the digital counter. Name Range: up to 12 alphanumeric characters Default: Counter 1 An alphanumeric name can be assigned to a digital counter for diagnostic, setting, and event recording purposes.
Page 389 CHAPTER 7: PROTECTION CONTROL ELEMENTS Set To Preset Range: any FlexLogic operand or shared operand Default: OFF This setting selects an operand used to set the count to the preset value and functions as follows: – The counter is set to the preset value when the counter is enabled and the operand assigned to the setting is asserted (logic 1).
Page 390: Flexcurves
CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 318: Digital counter logic FlexCurves Plus There are four user-programmable FlexCurves available with the D90 system, labeled A, B, C, and D. The curve shapes for the four FlexCurves are derived from the following equations: Eq.
Page 391 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 319: FlexCurve configuration settings The following settings are available for each custom FlexCurve. FlexCurve Name Range: up to 20 alphanumeric characters Default: FlexCurve A This setting specifies a user-defined name for the FlexCurve. Initialize From Range: IEEE Moderately Inverse, IEEE Very Inverse, IEEE Extremely Inverse, IEC Curve A, IEC Curve B, IEC Curve C, IEC Short Inverse, IAC Extreme Inv, IAC Very Inverse, IAC Inverse, IAC Short Inverse, I Squared T, Recloser Curve, FlexCurve A, FlexCurve B, FlexCurve C,...
Page 392 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 320: FlexCurve display example Prospective FlexCurves can be configured from a selection of standard curves to provide the best approximate fit, then specific data points can be edited afterwards. Click the Initialize FlexCurve button to populate the pickup values with the points from the curve specified by the setting.
Page 393 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 321: Recloser curve initialization The multiplier and adder settings affect the curve portion of the characteristic and not the NOTE: MRT and HCT settings. The HCT settings override the MRT settings for multiples of pickup greater than the HCT ratio.
Page 394: Protection Inputs And Outputs
PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 323: Composite recloser curve with HCT enabled Configuring a composite curve with an increase in operating time at increased pickup NOTE: Plus multiples is not allowed. If this is attempted, the EnerVista UR Setup software generates an error message and discards the proposed changes.
Page 395 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 324: Protection virtual inputs configuration settings The following settings are available for each protection virtual input. The default values outlined are for virtual input 1. Function Range: Enabled, Disabled Default: Disabled If this setting is “Disabled,” the virtual input is forced to off (logic 0) regardless of any attempt to alter the input.
Page 396: Protection Virtual Outputs
PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 325: Protection virtual input logic Protection virtual input actual values Select the Actual Values > Protection > Protection Inputs/Outputs > Virtual Inputs menu to open the protection virtual input actual values window. Figure 326: Protection virtual input actual values The following actual values are available for all enabled protection virtual inputs.
Page 397 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 327: Protection virtual output settings The following settings are available for each protection virtual output. If not assigned, the virtual output is forced to off (logic 0). Range: up to 12 alphanumeric characters Default: Virt Op 1 This setting specifies an identifier that can be assigned to each protection virtual output.
Page 398: Contact Input Configuration
PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Status Range: On, Off This value indicates the logic state of the protection virtual output. Contact input configuration Plus The D90 can monitor the status of up to 115 field contacts. Each input can be wetted Plus from the D90 48 volt auxiliary supply or from an external power supply.
Page 399 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS state is recognized immediately. Statistically, a delay of half the protection pass is expected. Owing to the 0.25 ms scan rate, the time resolution for the input contact is less than 1 ms. For example, 16 protection passes per cycle on a 60 Hz system correspond to a protection pass every 1.04 ms.
Page 400 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 330: Contact input and output assignments All available contact inputs and outputs can be reassigned using the >> and << buttons. Contact input settings When the input detects a voltage decrease, the input circuitry draws 10 mA of current. If the voltage decrease is due to a state change then the voltage quickly decreases, speeding up the recognition of the reset of the field contact.
Page 401 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Range: up to 12 alphanumeric characters Default: Cont Ip 1 An alphanumeric ID can be assigned to a contact input for diagnostic, setting, and event recording purposes. The “CONTACT IP 1” text in event records and FlexLogic operands are replaced by the text programmed in this setting.
Page 402 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 332: Chatter detection example Select the Settings > Protection > Protection Inputs/Outputs > Contact Inputs > Chatter Detection menu to access the contact input chatter detection settings. Figure 333: Contact input chatter detection configuration The following settings are applied to all available protection and automation contact inputs.
Page 403: Contact Outputs
CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 334: Protection contact input actual values The following actual values are available for all protection contact inputs. Name Range: up to 12 alphanumeric characters This value displays the programmed for the corresponding protection contact input. Status Range: On, Off This value indicates the logic state of the protection contact input.
Page 404: Direct Inputs
PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Seal-In Range: any FlexLogic operand or shared operand Default: as shown above This setting selects an operand (virtual output, element state, contact input, or virtual input) that seals-in the contact output when asserted. Voltage Threshold Range: 20 to 250 volts in steps of 1 Default: 20...
Page 405 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 337: Direct inputs configuration settings The following settings are available all direct inputs. The settings outlined are for direct input 1. Direct Input 1 Device ID Range: 0 to 16 in steps of 1 Default: 0 This setting represents the source of the direct input.
Page 406: Direct Outputs
PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Direct input states Select the Actual Values > Protection > Protection Inputs/Outputs > Direct Inputs menu to open the direct input states window. Figure 338: Direct inputs states The following actual values are available for all direct inputs, where input 1 is used as the example.
Page 407: Teleprotection Inputs And Outputs
CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 340: Direct output configuration settings The following settings are available for all direct outputs. The default values outlined are for direct output 1. Direct Input 1 Operand Range: any FlexLogic operand Default: Off This setting specifies the FlexLogic operand that determines the state of the direct output.
Page 408 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 341: Teleprotection inputs and outputs processing Teleprotection input settings Select the Settings > Protection > Protection Inputs/Outputs > Teleprotection > Teleprotection Inputs menu to open the teleprotection inputs configuration window. Figure 342: Teleprotection inputs configuration settings PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 409 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS The following setting is available for all 16 teleprotection inputs on channels 1 and 2. Teleprotection Input 1 Default States Range: Off, On, Latest/Off, Latest/On Default: Off Programming this setting to “On” defaults the input to logic 1 when the channel fails. A value of “Off”...
Page 410: Using Shared Operands In Protection
PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 344: Teleprotection input states The following actual value is available for all 16 teleprotection inputs on channels 1 and 2. Teleprotection Input 1 State Range: Off, On, Latest/On, Latest/Off This actual value displays the state of the teleprotection input on channels 1 and 2. The “Latest/On”...
Page 411 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 345: Default operand list by function The content of each operand list depends on the order code. The shared operands functionality expands upon this system. An output from any element Plus can be assigned as a shared operand within the EnerVista UR Setup software.
Page 412: Protection Flexlogic
PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION Figure 346: Shared operands configuration window Plus The left side of this screen displays all D90 operands that are available to the protection function as shared operands. Select any operands from the other five primary features by clicking the >>...
Page 413 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC Plus Figure 347: UR -series architecture overview Plus The states of all digital signals used in the D90 are represented by flags (or FlexLogic operands, which are described later in this section). A logic 1 state is represented by a set flag.
Page 414 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION The logic that determines the interaction of inputs, elements, schemes and outputs is programmable through the use of logic equations that are sequentially processed. The use of virtual inputs and outputs in addition to hardware is available internally and on the communication ports for other relays to use (distributed FlexLogic).
Page 415: Protection Flexlogic Gates And Operators
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC Type State Example Characteristics (input is logic 1 or “on” if...) Element Pickup The output operand is at logic 1 DIG ELEM 1 PKP (digital) Dropout This operand is the logical inverse of the DIG ELEM 1 DPO pickup operand Operate The input operand has been at logic 1 for the...
Page 416: Flexlogic Rules
PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION Type Syntax Description Operation Logic A logical NOT gate Operates on the previous gates parameter AND(n) An n-input AND gate, n = 1 to 16 Operates on the previous n parameters OR(n) An n-input OR gate, n = 1 to 16 Operates on the previous n parameters NOR(n)
Page 417: Protection Flexlogic Timers
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC Figure 348: Protection FlexLogic configuration settings A graphical representation of the protection FlexLogic can be displayed by clicking the View button at the top of the equation. Figure 349: Typical protection FlexLogic display Protection FlexLogic timers There are 32 identical protection FlexLogic timers available.
Page 418: Non-Volatile Latches
PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION Dropout Delay Range: 0 to 3600000000 ms in steps of 1 Default: 0 This setting specifies the time delay to dropout. If a dropout delay is not required, set this value to “0.” Non-volatile latches The non-volatile latches provide a permanent logical flag that is stored safely and does not reset upon reboot after the relay is powered down.
Page 419: Protection Flexelements
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC Table 25: Non-volatile latch operation table Type Latch operation Reset Reset-dominant Previous state Previous state Set-dominant Previous state Previous state The figure shows the logic diagram for protection non-volatile latches. Figure 352: Non-volatile latch logic Protection FlexElements A FlexElement is a universal comparator that can be used to monitor any analog actual value calculated by the relay or a net difference between any two analog actual values of...
Page 420 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION Figure 353: Protection FlexElements configuration settings The following settings are available for each protection FlexElement. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the corresponding FlexElement. Name Range: up to 6 alphanumeric characters Default: FxE 1 An alphanumeric identifier can be assigned to a FlexElement for diagnostic, setting, and event recording purposes.
Page 421 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC Input Mode Range: Signed, Absolute Default: Signed If this setting value is “Signed,” then the FlexElement responds directly to the differential signal. If this setting value is “Absolute,” then the FlexElement responds to the absolute value of the differential signal.
Page 422 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION Figure 354: Relationship of input mode and direction settings Pickup Range: –90.000 to 90.000 pu in steps of 0.001 Default: 1.000 pu This setting specifies the operating threshold for the effective operating signal of the FlexElement.
Page 423 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC Element Base unit Source current Maximum nominal primary RMS value of the +IN and –IN inputs Source power Maximum value of the product of the voltage and current base values for the +IN and –IN inputs Source voltage Maximum nominal primary RMS value of the +IN and –IN inputs Hysteresis...
Page 424: Customizing The Protection Flexlogic Operands
PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION Block Range: any FlexLogic operand or shared operand Default: Off Assertion of the operand assigned to this setting blocks operation of the FlexElement. Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of FlexElement events in the sequence of events recorder.
Page 425: Protection Flexlogic Operands
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC User Configured Event Name Range: up to 20 alphanumeric characters Default: --- Each available protection FlexLogic operand can be renamed to a user-specified value. This feature allows users to rename operands to allow for clearer identification or to match specific applications.
Page 426 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION Auxiliary undervoltage operands AUX UV1 DPO ..........Asserted when the auxiliary undervoltage element drops out. AUX UV1 OP..........Asserted when the auxiliary undervoltage element operates. AUX UV1 PKP..........Asserted when the auxiliary undervoltage element picks up. Breaker configuration operands BKR1 ANY POLE OPEN......Asserted when at least one pole of breaker 1 is open.
Page 427 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC BKR FAIL 1 RETRIPA........Asserted when breaker failure 1 re-trips on phase A (single-pole schemes only). BKR FAIL 1 RETRIPB........Asserted when breaker failure 1 re-trips on phase B (single-pole schemes only). BKR FAIL 1 RETRIPC........Asserted when breaker failure 1 re-trips on phase C (single-pole schemes only).
Page 428 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION DCUB TRIP A..........Asserted when the directional comparison unblocking scheme operates to trip phase A. DCUB TRIP B..........Asserted when the directional comparison unblocking scheme operates to trip phase B. DCUB TRIP C..........Asserted when the directional comparison unblocking scheme operates to trip phase C.
Page 429 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC DUTT TX3 ............Asserted when the direct underreaching transfer trip scheme asserts transmit bit 3. DUTT TX4 ............Asserted when the direct underreaching transfer trip scheme asserts transmit bit 4. FlexMatrix operands FLXMAT 1 DPO..........Asserted when FlexMatrix 1 drops out. FLXMAT 1 OP ..........Asserted when FlexMatrix 1 operates.
Page 430 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION HYBRID POTT TRIP A.........Asserted when the hybrid permissive overreaching transfer trip scheme operates to trip phase A. HYBRID POTT TRIP B.........Asserted when the hybrid permissive overreaching transfer trip scheme operates to trip phase B. HYBRID POTT TRIP C.........Asserted when the hybrid permissive overreaching transfer trip scheme operates to trip phase C.
Page 431 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC NEG SEQ DIR OC2 REV......Asserted when the negative-sequence directional overcurrent 2 element reverse mode operates. Negative-sequence instantaneous overcurrent operands NEG SEQ IOC1 DPO ........Asserted when the negative-sequence instantaneous overcurrent 1 element drops out. NEG SEQ IOC1 OP........Asserted when the negative-sequence instantaneous overcurrent 1 element operates.
Page 432 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION NEUTRAL TOC 2 to 6.........The operands listed above are also available for neutral time overcurrent 2 through 6. Neutral directional overcurrent operands NTRL DIR OC1 FWD........Asserted when the neutral directional overcurrent 1 element forward mode operates. NTRL DIR OC1 REV........Asserted when the neutral directional overcurrent 1 element reverse mode operates.
Page 433 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC PH DIST Z1 DPO CA ........Asserted when phase distance zone 1 phase CA drops out. PH DIST Z1 OP..........Asserted when phase distance zone 1 operates. PH DIST Z1 OP AB........Asserted when phase distance zone 1 phase AB operates. PH DIST Z1 OP BC........Asserted when phase distance zone 1 phase BC operates.
Page 434 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION PHASE OV1 DPO B........Asserted when phase B of the phase overvoltage 1 element drops out. PHASE OV1 DPO C........Asserted when phase C of the phase overvoltage 1 element drops out. PHASE OV1 OP ..........Asserted when at least one phase of the phase overvoltage 1 element operates.
Page 435 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC PHASE TOC1 OP B ........Asserted when phase B of the phase time overcurrent 1 element operates. PHASE TOC1 OP C........Asserted when phase C of the phase time overcurrent 1 element operates. PHASE TOC1 PKP........Asserted when at least one phase of the phase time overcurrent 1 element picks up.
Page 436 PROTECTION FLEXLOGIC CHAPTER 7: PROTECTION POTT TRIP C ..........Asserted when the permissive over-reaching transfer trip scheme operates to trip phase C. POTT TX ............Asserted when the permissive signal is sent. POTT TX1............Asserted when the permissive over-reaching transfer trip scheme asserts transit bit number 1. POTT TX2............Asserted when the permissive over-reaching transfer trip scheme asserts transit bit number 2.
Page 437: Protection Flexanalog Parameters
CHAPTER 7: PROTECTION PROTECTION FLEXANALOG PARAMETERS Setting group operands SETTING GROUP ACT 1......Asserted when setting group 1 is active. SETTING GROUP ACT 2......Asserted when setting group 2 is active. SETTING GROUP ACT 3......Asserted when setting group 3 is active. SETTING GROUP ACT 4......Asserted when setting group 4 is active. SETTING GROUP ACT 5......Asserted when setting group 5 is active.
Page 438 PROTECTION FLEXANALOG PARAMETERS CHAPTER 7: PROTECTION Digital Counter 6 Value......Actual value of digital counter 6 Digital Counter 7 Value......Actual value of digital counter 7 Digital Counter 8 Value......Actual value of digital counter 8 FlexElement analog operands FlexElement 1 Value.........Metered value for FlexElement 1 FlexElement 2 Value.........Metered value for FlexElement 2 FlexElement 3 Value.........Metered value for FlexElement 3 FlexElement 4 Value.........Metered value for FlexElement 4...
Page 439: Automation
Plus Line Distance Protection System Chapter 8: Automation Automation Plus This section outlines how to program the D90 automation features. Automation controller overview Plus The D90 automation controller allows custom automation schemes. The controller can access both digital and analog inputs and outputs. Operations carried out on digital inputs and outputs are referred to as logical operations, whereas operations carried out on analog inputs and outputs are referred to as math operations.
Page 440: Input And Output Structure
AUTOMATION CONTROLLER OVERVIEW CHAPTER 8: AUTOMATION Input and output structure Plus The figure shows the input and output structure of the D90 . Three groupings of inputs and outputs are defined (physical, shared, and virtual), with digital and analog types within each grouping.
Page 441: Breakers
CHAPTER 8: AUTOMATION BREAKERS Plus passed to the automation function and vice-versa. The D90 can store a total of 64 shared operands. This allows the automation function access to a large variety of analog measurements resident in the protection functions. •...
Page 442 BREAKERS CHAPTER 8: AUTOMATION Local Control Range: any automation logic operand or shared operand Default: L/R-L On When the operand assigned to this setting is asserted, control is enabled from the front panel interface. This setting normally is assigned to the local status of a local/remote switch.
Page 443 CHAPTER 8: AUTOMATION BREAKERS Bypass Time Range: 0.0 to 30.0 seconds in steps of 0.1 Default: 10.0 seconds This setting specifies the time window during which non-interlocked control can occur once bypass has been selected. The following figures provide the breaker control logic. Figure 361: Breaker control logic, sheet 1 of 3 PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 444: Breaker Interlocking
BREAKERS CHAPTER 8: AUTOMATION Figure 362: Breaker control logic, sheet 2 of 3 Figure 363: Breaker control logic, sheet 3 of 3 Breaker interlocking The breaker interlocking element contains the auxiliary logic for interlocking of circuit breakers. Up to three inputs can be assigned for interlocking the open and close controls. An input is also available for supervision by a synchrocheck element.
Page 445 CHAPTER 8: AUTOMATION BREAKERS Figure 364: Breaker interlocking configuration settings The following settings are available for each breaker interlocking element. Function Range: Enabled, Disabled Default: Disabled This setting enables the breaker position indications and control logic. If disabled, all outputs and front panel indications are switched off. Tagging Range: Enabled, Disabled Default: Disabled...
Page 446: Disconnects
DISCONNECTS CHAPTER 8: AUTOMATION Events Range: Enabled, Disabled Default: Enabled The setting enables or disables the logging of breaker interlocking events in the sequence of events recorder. The figure shows the breaker interlocking logic. Figure 365: Breaker interlocking logic Disconnects The disconnect element contains the auxiliary logic for status and serves as the interface for opening and closing of the disconnect from protection and automation functions.
Page 447 CHAPTER 8: AUTOMATION DISCONNECTS Figure 366: Disconnect configuration settings The following settings are available for each disconnect. Function Range: Enabled, Disabled Default: Enabled This setting enables the disconnect position indications and control logic. If disabled, all outputs and front panel indications are switched off. Long Name Range: up to 12 alphanumeric characters Default: DISCONNECT 1...
Page 448 DISCONNECTS CHAPTER 8: AUTOMATION Disconnect Local Input Range: any automation logic operand or shared operand Default: OFF Closing or opening of the disconnect through the disconnect interlock element is inhibited if the operand assigned to this setting is asserted. Indication Mode Range: 3-Pole, 1-Pole Default: 3-Pole If the “3-Pole”...
Page 449 CHAPTER 8: AUTOMATION DISCONNECTS Operate Time Range: 0.000 to 2.000 seconds in steps of 0.001 Default: 0.070 seconds This setting specifies a timer that is asserted when both the normally open and normally closed disconnect indications are reset. When the timer expires, a bad status is indicated for the disconnect.
Page 450 DISCONNECTS CHAPTER 8: AUTOMATION Figure 368: Disconnect logic, sheet 2 of 4 Figure 369: Disconnect logic, sheet 3 of 4 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 451: Disconnect Control
CHAPTER 8: AUTOMATION DISCONNECTS Figure 370: Disconnect logic, sheet 4 of 4 Disconnect control The disconnect control element contains the auxiliary logic for control of circuit breakers required for SCADA and the front panel interface. The control function incorporates select- before-operate functionality.
Page 452 DISCONNECTS CHAPTER 8: AUTOMATION Figure 371: Disconnect control configuration settings The following settings are available for each disconnect. Function Range: Enabled, Disabled Default: Enabled This setting enables and disables the disconnect control feature. Pushbutton Control Range: Enabled, Disabled Default: Enabled This setting enables control of the device via the front panel and populates the front panel interface with control soft-keys.
Page 453 CHAPTER 8: AUTOMATION DISCONNECTS Automatic Open Range: any automation logic operand or shared operand Default: OFF The operand assigned to this setting is used to open the device from an automatic control scheme. Execute Time Range: 0.0 to 10.0 seconds in steps of 0.1 Default: 10.0 seconds This setting specifies the duration of the open and close commands used to control the disconnect.
Page 454: Disconnect Interlocking
DISCONNECTS CHAPTER 8: AUTOMATION Figure 373: Disconnect control logic, sheet 2 of 3 Figure 374: Disconnect control logic, sheet 3 of 3 Disconnect interlocking The disconnect interlocking element contains the auxiliary logic for interlocking of disconnects. Up to three inputs can be assigned for interlocking the open and close controls.
Page 455 CHAPTER 8: AUTOMATION DISCONNECTS Figure 375: Disconnect interlocking configuration settings The following settings are available for each disconnect. Function Range: Enabled, Disabled Default: Disabled This setting enables the disconnect position indications and control logic. If “Disabled,” all outputs and front panel indications are switched off. Tagging Range: Enabled, Disabled Default: Disabled...
Page 456: Automation Control
AUTOMATION CONTROL CHAPTER 8: AUTOMATION Figure 376: Disconnect interlocking logic Automation control This section outlines the control elements used for automation. Front panel status and control There can be a maximum of six breakers and 6 disconnect switches (referred to as devices) plus autoreclose and local-remote status and control.
Page 457 CHAPTER 8: AUTOMATION AUTOMATION CONTROL Figure 377: Device selected to operate A confirmation message is displayed using the full name for the device to be controlled. If no buttons are pressed, the control action is canceled after the select time timer expires. The control action can be cancelled by pushing the CANCEL key.
Page 458: Local-Remote Control Scheme
AUTOMATION CONTROL CHAPTER 8: AUTOMATION Figure 379: Breaker 1 status substituted The following indications are provided for breakers and disconnects. Figure 380: Front panel indicators for breakers and disconnects Local-remote control scheme The local-remote control scheme is used to define the current location for operator control of power system devices (for example, breakers, disconnects).
Page 459 CHAPTER 8: AUTOMATION AUTOMATION CONTROL Figure 381: Local-remote control configuration settings The following settings are available for the local-remote control scheme. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the local-remote control scheme automation logic and front panel indications. Pushbutton Control Range: Enabled, Disabled Default: Enabled...
Page 460: Synchrocheck
AUTOMATION CONTROL CHAPTER 8: AUTOMATION Figure 382: Local-remote control logic Synchrocheck The are two identical synchrocheck elements available, numbered 1 and 2. The synchrocheck (synchronism check) function is intended for supervising the paralleling of two parts of a system that are to be joined by the closure of a circuit breaker. The synchrocheck elements typically are used at locations where the two parts of the system are interconnected through at least one other point in the system.
Page 461 CHAPTER 8: AUTOMATION AUTOMATION CONTROL or V (source Y) V or V (source Z) Auto-selected combination Auto-selected voltage Source Y Source Z Phase VTs and Phase VT Phase Phase auxiliary VT Phase VT Phase VT Phase Phase Phase VT and Auxiliary VT Phase Auxiliary...
Page 462 AUTOMATION CONTROL CHAPTER 8: AUTOMATION Function Range: Enabled, Disabled Default: Disabled This setting enables the synchrocheck position indications and control logic. If disabled, all synchrocheck outputs and front panel indications are switched off. Block Range: any automation logic operand or shared operand Default: BKR1 CLOSED Assertion of the operand assigned to this setting blocks operation of the synchrocheck element.
Page 463 CHAPTER 8: AUTOMATION AUTOMATION CONTROL Dead Source Select Range: None, LV1 and DV2, DV1 and LV2, DV1 or DV2, DV1 Xor DV2, DV1 and DV2 Default: LV1 and DV2 This setting selects the combination of dead and live sources that bypass the synchronism check function and permit the breaker to be closed when one or both of the two voltages (V and V...
Page 464 AUTOMATION CONTROL CHAPTER 8: AUTOMATION Figure 384: Synchrocheck logic, sheet 1 of 2 Figure 385: Synchrocheck logic, sheet 2 of 2 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 465: Selector Switch
CHAPTER 8: AUTOMATION AUTOMATION CONTROL Selector switch The selector switch element replaces a mechanical selector switch. Typical applications include setting group control or control of multiple logic sub-circuits in user-programmable logic. Selector switch operation The selector switch provides for two control inputs. The step-up control allows stepping through selector position one step at a time with each pulse of the control input, such as a user-programmable pushbutton.
Page 466 AUTOMATION CONTROL CHAPTER 8: AUTOMATION Figure 386: Time-out mode PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 467 CHAPTER 8: AUTOMATION AUTOMATION CONTROL Figure 387: Acknowledge mode Selector switch settings Select the Settings > Automation > Control > Selector Switches menu to open the selector switch configuration window. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 468 AUTOMATION CONTROL CHAPTER 8: AUTOMATION Figure 388: Selector switch configuration settings The following settings are available for each selector switch. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the selector switch. Full Range Range: 1 to 7 in steps of 1 Default: 7 This setting specifies the upper position of the selector switch.
Page 469 CHAPTER 8: AUTOMATION AUTOMATION CONTROL Step-Up Mode Range: Time-out, Acknowledge Default: Time-out This setting defines the selector mode of operation. When set to “Time-out,” the selector changes its position after a pre-defined period of inactivity at the control input. The change is automatic and does not require any explicit confirmation of the intent to change the selector's position.
Page 470 AUTOMATION CONTROL CHAPTER 8: AUTOMATION 3-Bit Mode Range: Time-out, Acknowledge Default: Time-out This setting selects the selector mode of operation. When set to “Time-out,” the selector changes its position after a pre-defined period of inactivity at the control input. The change is automatic and does not require explicit confirmation to change the selector position.
Page 471: Automation Inputs And Outputs
CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS SELECTOR 1 POS 4 ..Selector 1 changed its position to 4. SELECTOR 1 POS 5 ..Selector 1 changed its position to 5. SELECTOR 1 POS 6 ..Selector 1 changed its position to 6. SELECTOR 1 POS 7 ..
Page 472 AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION Figure 390: Automation virtual inputs configuration settings The following settings are available for each automation virtual input. The default values outlined are for virtual input 1. Function Range: Enabled, Disabled Default: Disabled If this setting is “Disabled,” the virtual input is forced to off (logic 0) regardless of any attempt to alter the input.
Page 473: Automation Virtual Outputs
CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS Figure 391: Automation virtual input logic Automation virtual outputs There are 255 virtual outputs that can be assigned via automation logic. Virtual outputs are resolved in each pass through the evaluation of the automation logic equations. Select the Settings >...
Page 474: Contact Input And Output Default Assignment
AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION Figure 393: Automation virtual output programming example Contact input and output default assignment When a new settings file is created, the available contacts are assigned automatically to the protection or automation functions according to the following convention: First I/O module →...
Page 475: Contact Input Configuration
CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS Figure 394: Contact input and output assignments All available contact inputs and outputs can be reassigned using the >> and << buttons. Contact input configuration Plus The D90 can monitor the status of up to 115 field contacts. Each input can be wetted Plus from the D90 48 volt auxiliary supply or from an external power supply.
Page 476 AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION Figure 395: Automation contact input debouncing mechanism and time-stamping Automation equations and timers are executed at the automation scan rate. The automation operand reflecting the debounced state of the contact is updated at the automation pass following the validation (mark 3 in the figure).
Page 477 CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS When the input detects a voltage decrease, the input circuitry draws 10 mA of current. If the voltage decrease is due to a state change then the voltage quickly decreases, speeding up the recognition of the reset of the field contact by quickly discharging any input capacitance.
Page 478 AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION Nominal voltage Validation threshold 48 V 33.6 V 125 V 87.5 V 250 V 175 V Events Range: Enabled, Disabled Default: Enabled If this setting is “Enabled,” every change in the contact input state triggers an event in the event recorder.
Page 479: Contact Outputs
CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the chatter detection feature. Chatter Time Range: 1 to 100 seconds in steps of 1 Default: 10 seconds This setting specifies the length of time that the relay contacts are monitored for contact input state changes.
Page 480 AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION Voltage Threshold Range: 20 to 250 volts in steps of 1 Default: 20 This setting specifies the level at which the Contact Op 1 VOn and Contact Op 1 VOff operands function. It is only shown for contact outputs that have monitoring. Events Range: Enabled, Disabled Default: Enabled...
Page 481: Virtual Analog Outputs
CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS Virtual analog outputs There are 128 virtual analog outputs that can be assigned using automation logic. Virtual analog outputs are resolved in each pass through the evaluation of the automation logic equations. Select the Settings > Automation > Automation Inputs/Outputs > Virtual Analogs menu to access the virtual analog output configuration settings.
Page 482 AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION Figure 403: Default operand list by function The content of each operand list depends on the order code. The shared operands functionality expands upon this system. An output from any element Plus can be assigned as a shared operand within the EnerVista UR Setup software.
Page 483: Automation Logic
CHAPTER 8: AUTOMATION AUTOMATION LOGIC Figure 404: Shared operands configuration window Plus The left side of this screen displays all D90 operands that are available to the automation function as shared operands. Select any operands from the other five primary features by clicking the >>...
Page 484 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Plus Figure 405: UR -series architecture overview Plus The states of all digital signals used in the D90 are represented by flags (or automation logic operands, described later in this section). A logic 1 state is represented by a set flag. Any external contact change-of-state can be used to block an element from operating, as an input to a control feature in an automation logic equation, or to operate a contact output.
Page 485 CHAPTER 8: AUTOMATION AUTOMATION LOGIC The logic that determines the interaction of inputs, elements, schemes and outputs is field programmable through the use of logic equations that are sequentially processed. The use of virtual inputs and outputs in addition to hardware is available internally and on the communication ports for other relays to use (distributed logic).
Page 486: Automation Operators
AUTOMATION LOGIC CHAPTER 8: AUTOMATION Type State Example Characteristics (input is logic 1 or “on” if...) Virtual The virtual output is presently in the on state VIRT OP 1 ON output Automation operators The following operators are available for the creation of automation logic: •...
Page 487 CHAPTER 8: AUTOMATION AUTOMATION LOGIC Table 33: Automation logic Boolean operators and latches Syntax Description Output is ON if... Logical NOT gate. Operates on the previous the input is logic 0 operand. Logical OR gates. Operate on the previous 2 to 16 any input is logic 1 OR(2) OR(16)
Page 488 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Syntax Description Return the largest integer less than or equal to the operand FLOOR Return the remainder of the first operand divided by the second operand FMOD (a, b) Return the imaginary value of the previous two operands, where the first IMAG (a,b) operand is the magnitude and the second operand is the angle Return the natural logarithm (base e) value of the previous operand...
Page 489 CHAPTER 8: AUTOMATION AUTOMATION LOGIC AVO1 = 20 // initialize virtual analog output 1 to 20 AVO1 + SRC4 Ig RMS = AVO3 // add an offset of 20 to the Ig RMS Automation virtual outputs The table outlines automation virtual output syntax. Table 35: Automation virtual output operators Syntax Description...
Page 490 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Figure 410: Using comparators to verify approximate equivalence Automation timers Plus Unlike earlier versions of the D90 , automation timers are implemented like gates or latches and not through setting menus. Automation timers have the following syntax: TIMER (IN, PKP, DPO).
Page 491: Automation Logic Equation Editor
CHAPTER 8: AUTOMATION AUTOMATION LOGIC Figure 412: Using virtual analogs to control automation timers Automation logic equation editor An automation logic equation can contain up to 4096 entries, including the operator. If a disabled element is selected as an automation logic entry, the associated state flag is never asserted (set to logic 1).
Page 492 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Figure 414: Typical automation logic display Automation logic rules When forming an automation logic equation, the sequence in the linear array of parameters must follow these general rules: There are two types of operators: logic operators and math operators. Logic operands must precede the logic operator that uses the operands as inputs.
Page 493 CHAPTER 8: AUTOMATION AUTOMATION LOGIC The following logic calculates the magnitude and angle of I × Z and assigns these results to virtual analog 2 and virtual analog 3, respectively. Figure 415: Magnitude and angle calculation logic for I × Z The following logic calculates the real and imaginary parts of the local positive-sequence voltage and assigns these results to virtual analog 4 and virtual analog 5, respectively.
Page 494 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Figure 418: Remote voltage magnitude calculation logic Now that the remote voltage magnitude has been calculated, the following logic calculates the voltage difference between this and the setting voltage. Figure 419: Voltage difference automation logic The current on each phase is checked to ensure that it is less than the maximum allowable for a tap changer operation.
Page 495 CHAPTER 8: AUTOMATION AUTOMATION LOGIC A lockout is implemented with the following logic. The lockout is asserted if the tap changer gas trip contact is picked up (63GT). The lockout also is asserted if the tap changer remains between taps for more than 10 seconds. The lockout is latched until manually reset.
Page 496 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Figure 423: Raise command automation logic The following automation logic detects excessive tap changer operations. First, a TIMEOUT signal is created that produces a one second pulse once an hour. Figure 424: Timeout signal automation logic A counter is then implemented to accumulate the number of operations (indicated by the OFF TAP signal).
Page 497: Customizing The Automation Logic Operands
CHAPTER 8: AUTOMATION AUTOMATION LOGIC Figure 426: Maximum operations per hour alarm automation logic Customizing the automation logic operands Select the Settings > Configure FlexOperands menu to open the user-configurable operands window. Figure 427: User-configurable automation logic operands window Plus The left side of this window displays all operands that are currently available to the D90 The automation logic operands are displayed by expanding the Automation entry.
Page 498 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Aut VO 2 to 255...........The operands listed above are available for the automation virtual outputs 2 through 255. These operands reflect the programmed names for the automation virtual outputs. Breaker control operands BKR CNTRL1 CLOSE CMD .......Asserted when a close command is issued on breaker 1 from breaker control.
Page 499 CHAPTER 8: AUTOMATION AUTOMATION LOGIC Disconnect interlock operands DISC INTERLK1 CLS PERM ......Asserted when all conditions have been satisfied for closing disconnect 1. DISC INTERLK1 OPEN PERM ....Asserted when all conditions have been satisfied for opening disconnect 1. DISC INTERLK1 TAGGED......Asserted when a tag is applied to disconnect 1. DISC INTERLK2..........The operands listed above are available for all disconnect interlocking elements.
Page 500 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Selector switch operands SELECTOR 1 ALARM ........Asserted when the position of selector 1 has been pre-selected but not acknowledged. SELECTOR 1 BIT 0........Represents the first bit of the three-bit word encoding position of selector 1. SELECTOR 1 BIT 1........Represents the second bit of the three-bit word encoding position of selector 1.
Page 501: Automation Flexanalog Parameters
CHAPTER 8: AUTOMATION AUTOMATION FLEXANALOG PARAMETERS Automation FlexAnalog parameters The following automation FlexAnalog parameters (analog operands) are available for the Plus . They are listed alphabetically by operand syntax. Synchrocheck analog operands Synchchk 1 Delta V ........Metered voltage difference for the synchrocheck 1 element Synchchk 1 Delta F........Metered frequency difference for the synchrocheck 1 element Synchchk 1 Delta Phs ......Metered phase difference for the synchrocheck 1 element Synchchk 2 Delta V ........Metered voltage difference for the synchrocheck 2 element...
Page 502 AUTOMATION FLEXANALOG PARAMETERS CHAPTER 8: AUTOMATION PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 503: Equipment Manager
Plus Line Distance Protection System Chapter 9: Equipment manager Equipment manager A program for equipment monitoring can result in extended equipment life, improved system reliability, and increased equipment availability. Effective equipment monitoring allows maintenance to be targeted towards the equipment with the greatest need. Overview of equipment manager Plus The D90...
Page 504: Circuit Breaker Arcing Management
CIRCUIT BREAKER ARCING MANAGEMENT CHAPTER 9: EQUIPMENT MANAGER Figure 428: Equipment manager block diagram Circuit breaker arcing management The breaker arcing management function indicates the condition of the circuit breaker interrupter. The primary function is measurement of accumulated contact wear. This is accomplished by integrating the current passing through the breaker during interruption.
Page 505 CHAPTER 9: EQUIPMENT MANAGER CIRCUIT BREAKER ARCING MANAGEMENT Figure 429: Breaker arcing current measurement Select the Settings > Equipment Manager > Breaker > Breaker Arcing menu to open the breaker arcing current configuration window. Figure 430: Breaker arcing current configuration settings The following settings are available for each breaker arcing current element.
Page 506 CIRCUIT BREAKER ARCING MANAGEMENT CHAPTER 9: EQUIPMENT MANAGER Exponent Range: 1.000 to 5.000 in steps of 0.001 Default: 2.000 This setting specifies the accumulated breaker wear that is proportional in the following equation, Eq. 45 where x is the arcing exponent. The typical value for the arcing exponent is 2. Interruption Rating Range: 0.0 to 100.0 kA in steps of 0.1 Default: 31.5 kA...
Page 507: Battery Monitor
CHAPTER 9: EQUIPMENT MANAGER BATTERY MONITOR Figure 431: Breaker arcing current logic Battery monitor The battery monitor checks the health of the DC battery system. It provides an analog indication of the current DC voltage derived from a contact input wired between the positive and negative rails of the battery system.
Page 508: Battery Monitor Settings
BATTERY MONITOR CHAPTER 9: EQUIPMENT MANAGER The figure shows typical wiring for the battery monitor element. Figure 432: Battery monitor wiring diagram Battery monitor settings Select the Settings > Equipment Manager > Battery Monitor menu to open the battery monitor configuration window. Figure 433: Battery monitor configuration settings The following settings are available.
Page 509 CHAPTER 9: EQUIPMENT MANAGER BATTERY MONITOR Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the battery monitor element. Input Range: any contact input or OFF Default: OFF This setting specifies the contact input used to monitor the battery voltage. High DC Volts Range: 38 to 275 volts in steps of 1 Default: 143 volts...
Page 510: Using Shared Operands In Equipment Manager
USING SHARED OPERANDS IN EQUIPMENT MANAGER CHAPTER 9: EQUIPMENT MANAGER Events Range: Enabled, Disabled Default: Enabled This setting enables and disables the logging of battery monitoring events in the sequence of events recorder. The figure shows the battery monitoring logic diagram. Figure 434: Battery monitor logic Using shared operands in equipment manager Plus...
Page 511: Shared Equipment Manager Operands
CHAPTER 9: EQUIPMENT MANAGER USING SHARED OPERANDS IN EQUIPMENT MANAGER Figure 435: Default operand list by function The content of each operand list depends on the order code. The shared operands functionality expands upon this system. An output from any element Plus can be assigned as a shared operand within the EnerVista UR Setup software.
Page 512: Renaming Equipment Manager Operands
USING SHARED OPERANDS IN EQUIPMENT MANAGER CHAPTER 9: EQUIPMENT MANAGER Figure 436: Shared operands configuration window Plus The left side of this screen displays all D90 operands that are available to the equipment manager as shared operands. Select any operands from the other five primary features by clicking the >>...
Page 513: Equipment Manager Operands
CHAPTER 9: EQUIPMENT MANAGER USING SHARED OPERANDS IN EQUIPMENT MANAGER Figure 437: User-configurable equipment manager logic operands window Plus The left side of this window displays all operands that are currently available to the D90 The equipment manager logic operands are displayed by expanding the Equipment Manager entry.
Page 514: Equipment Manager Flexanalog Parameters
EQUIPMENT MANAGER FLEXANALOG PARAMETERS CHAPTER 9: EQUIPMENT MANAGER BAT MON HIGH VDC PKP ......Asserted when the battery high DC voltage monitor picks up. BAT MON LOW VDC DPO......Asserted when the battery low DC voltage monitor drops out. BAT MON LOW VDC OP ......Asserted when the battery low DC voltage monitor operates. BAT MON LOW VDC PKP ......Asserted when the battery low DC voltage monitor picks up.
Page 515: Digital Fault Recorder
Plus Line Distance Protection System Chapter 10: Digital fault recorder Digital fault recorder The digital fault recorder (DFR) captures detailed information regarding abnormal occurrences in the power system. The information captured by the DFR is stored in the Plus in non-volatile memory and can be accessed through the front panel interface. The DFR consists of the following four functions: •...
Page 516: Fault Report
FAULT REPORT CHAPTER 10: DIGITAL FAULT RECORDER Figure 438: Example of sequence of events record Fault report Plus The D90 device supports one fault report and an associated fault locator. The signal source and trigger condition, as well as the characteristics of the line or feeder, are entered in the fault report configuration settings.
Page 517: Fault Report Operation
CHAPTER 10: DIGITAL FAULT RECORDER FAULT REPORT Otherwise the indication is red. In automatic overwrite mode, the Ready to Capture indication is green when all of the following conditions hold: • The fault report feature is enabled • The source for the fault report is properly configured •...
Page 518: Fault Type Determination
FAULT REPORT CHAPTER 10: DIGITAL FAULT RECORDER has not been reset (the OR gate output is still high), the fault report is not triggered again. Considering the reset time of protection elements, there is very little chance that fault report can be triggered twice in this manner. Each fault report is stored as a file, and the relay capacity is 15 files.
Page 519: Fault Report Settings
CHAPTER 10: DIGITAL FAULT RECORDER FAULT REPORT Inserting the I and I equations into the V equation and solving for R yields the fault resistance. Eq. 49 Assuming the fault components of the currents I and I are in phase, and observing A(F) B(F) that the fault resistance, as impedance, does not have any imaginary part gives the...
Page 520 FAULT REPORT CHAPTER 10: DIGITAL FAULT RECORDER Figure 442: Fault report configuration settings The following settings are available. Source Range: LINE (SRC 1), BKR 1 (SRC 2), BKR 2 (SRC 3) Default: SRC1 This setting selects the source for input currents, voltages, and disturbance detection. Trigger Range: any FlexLogic operand Default: OFF...
Page 521 CHAPTER 10: DIGITAL FAULT RECORDER FAULT REPORT Line Length Units Range: km, miles Default: km This setting selects the units used for fault location calculations. Line Length Range: 0.0 to 2000.0 in steps of 0.1 Default: 100.0 This setting specifies the length of the transmission line or feeder in the defined line length units.
Page 522: Transient Recorder
TRANSIENT RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Figure 443: Fault locator logic Transient recorder The transient recorder captures short duration events, such as faults at a high resolution. Under normal operation, the transient recorder continuously captures pre-fault data and stores this data in memory. When a trigger is received, the transient recorder captures the data during the period of the fault.
Page 523 CHAPTER 10: DIGITAL FAULT RECORDER TRANSIENT RECORDER Figure 444: Trigger and re-trigger sequence The length of a transient record also is user-configurable. The number of transient records Plus stored by the D90 is a function of the record length, the time-resolution of the recording, Plus and of the number of configured channels.
Page 524: Front Panel Indications
TRANSIENT RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Front panel indications The digital fault reporter summary screen indicates when the transient recorder is ready to capture data and has memory available. In protected mode, the Ready to Capture indication is green when all of the following conditions hold: •...
Page 525: Transient Recorder Settings
CHAPTER 10: DIGITAL FAULT RECORDER TRANSIENT RECORDER Figure 446: Transient recorder screen Transient recorder settings Select the Settings > DFR > Transient Record menu to open the transient recorder configuration window. Figure 447: Transient recorder configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Enabled...
Page 526 TRANSIENT RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Trigger Position Range: 1 to 100% in steps of 1 Default: 50% This setting specifies the amount of pre-trigger data stored in a record expressed as a percentage of record length. Maximum Re-Triggers Range: 1 to 4 in steps of 1 Default: 2 This setting selects the maximum number of re-trigger records that can be generated...
Page 527 CHAPTER 10: DIGITAL FAULT RECORDER TRANSIENT RECORDER Figure 448: Transient recorder trigger logic Transient recorder digital channels Up to 128 digital channels can be assigned to the transient recorder. Each channel can be configured individually by clicking the digital channels Select button in the transient recorder window to open the transient recorder digital channels window.
Page 528 TRANSIENT RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Signals Range: any FlexLogic operand or shared operand Default: OFF This setting specifies an operand to use as a transient recorder digital channel. The pull- down list of available signals is populated with enabled protection functions. Selected operands are assigned automatically as channels and as triggers according to their importance and can be de-assigned by the user.
Page 529 CHAPTER 10: DIGITAL FAULT RECORDER TRANSIENT RECORDER Transient recorder analog channels Up to 16 analog channels can be assigned to the transient recorder. Each channel can be configured individually by clicking the analog channel Select button in the transient recorder window to open the transient recorder analog channels window. Figure 451: Analog channel configuration settings The following settings are available for each analog channel.
Page 530 TRANSIENT RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Low Triggering Range: Enabled, Disabled Default: Disabled This setting selects the low triggering function for the analog channel. When set to “Trigger Only” or “Trigger/Re-Trigger,” the transient recorder initiates data capture when the magnitude of the signal is less than the value of the setting.
Page 531: Disturbance Recorder
CHAPTER 10: DIGITAL FAULT RECORDER DISTURBANCE RECORDER Figure 452: Analog channel trigger logic Disturbance recorder The disturbance recorder is designed to capture long duration events, such as power swings, at a resolution of one sample per cycle. Under normal operation, the disturbance recorder is capturing continuously the pre-event data and storing this data in memory.
Page 532 DISTURBANCE RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Figure 453: Trigger and re-trigger sequence The number of disturbance records also is user-configurable. The length of disturbance Plus records stored by the D90 is a function of the number of records and the number of Plus configured channels.
Page 533: Front Panel Indications
CHAPTER 10: DIGITAL FAULT RECORDER DISTURBANCE RECORDER The recorder has two storage modes: protected and automatic overwrite. When the memory is filled, either no new records are written to memory (protected mode) or the oldest record is overwritten (automatic overwrite mode). Front panel indications The digital fault reporter summary screen indicates when the disturbance recorder is ready to capture data and has memory available.
Page 534: Disturbance Recorder Settings
DISTURBANCE RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Figure 455: Disturbance recorder screen Disturbance recorder settings Select the Settings > DFR > Disturbance Record menu to open the disturbance recorder configuration window. Figure 456: Disturbance recorder configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled...
Page 535 CHAPTER 10: DIGITAL FAULT RECORDER DISTURBANCE RECORDER Trigger Position Range: 1 to 100% in steps of 1 Default: 50% This setting specifies the amount of pre-trigger data stored in a disturbance record expressed as a percentage of the disturbance record length. Maximum Re-Triggers Range: 1 to 4 in steps of 1 Default: 2...
Page 536 DISTURBANCE RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Disturbance recorder digital channels Up to 32 digital channels can be assigned to the disturbance recorder. Each channel can be configured individually by clicking the digital channels Select button in the disturbance recorder window to open the disturbance recorder digital channels window. Figure 458: Digital channel configuration settings The following settings are available for each disturbance recorder digital channel.
Page 537 CHAPTER 10: DIGITAL FAULT RECORDER DISTURBANCE RECORDER When set to “Trigger/Re-Trigger” or “Re-Trigger Only,” the disturbance recorder is re- triggered if the signal is still asserted at the end of the trigger period. The resulting record contains fault data only. A re-trigger is re-generated at the end of a disturbance record if the signal is still asserted and if the number of re-triggers is less than the value specified by the Maximum Re-Triggers...
Page 538 DISTURBANCE RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Available Signals Range: any FlexAnalog quantity Default: Off This setting specifies the FlexAnalog quantity to be recorded for the channel. The size of each disturbance record depends in part on the number of parameters selected. Parameters set to “Off”...
Page 539: Using Shared Operands In Digital Fault Recorder
CHAPTER 10: DIGITAL FAULT RECORDER USING SHARED OPERANDS IN DIGITAL FAULT RECORDER Block Trigger Range: any FlexLogic operand Default: Off The FlexLogic operand assigned to this setting blocks triggering of the disturbance recorder analog channel. Figure 461: Analog channel trigger logic Using shared operands in digital fault recorder Plus Plus...
Page 540: Shared Digital Fault Recorder Operands
USING SHARED OPERANDS IN DIGITAL FAULT RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Figure 462: Default operand list by function The content of each operand list depends on the order code. The shared operands functionality expands upon this system. An output from any element Plus can be assigned as a shared operand within the EnerVista UR Setup software.
Page 541: Digital Fault Recorder Flexanalog Parameters
CHAPTER 10: DIGITAL FAULT RECORDER DIGITAL FAULT RECORDER FLEXANALOG PARAMETERS Figure 463: Shared operands configuration window Plus The left side of this screen displays all D90 operands that are available to the digital fault recorder function as shared operands. Select any operands from the other five primary features by clicking the >>...
Page 542 DIGITAL FAULT RECORDER FLEXANALOG PARAMETERS CHAPTER 10: DIGITAL FAULT RECORDER Prefault Ia Mag [1]........Metered phase A pre-fault current magnitude from fault report Prefault Ia Ang [1]........Metered phase A pre-fault current angle from fault report Prefault Ib Mag [1]........Metered phase B pre-fault current magnitude from fault report Prefault Ib Ang [1]........Metered phase B pre-fault current angle from fault report Prefault Ic Mag [1]........Metered phase C pre-fault current magnitude from fault report Prefault Ic Ang [1]........Metered phase C pre-fault current angle from fault report...
Page 543: Metering
Plus Line Distance Protection System Chapter 11: Metering Metering Plus This chapter outlines how to program the D90 metering features. Metering source Select the Settings > Metering > Metering Source menu to open the metering source configuration window. Figure 464: Metering source configuration settings The following setting is available.
Page 544: Phasor Measurement Unit Configuration
Range: 16 alphanumeric characters Default: GE-UR+PMU This setting assigns an alphanumeric ID to the PMU station. It corresponds to the STN field of the configuration frame of the C37.118 protocol. This value is a 16-character ASCII string as per the C37.118 standard.
Page 545: Phasor Measurement Unit Calibration
CHAPTER 11: METERING PHASOR MEASUREMENT UNIT symmetrical components (0, 1, and 2) of both voltages and currents. When configuring communication and recording features of the PMU, the user can select—from the above superset—the content to be sent out or recorded. Post-Filter Range: None, Symm-3-point, Symm-5-point, Symm-7-point Default: Symm-3-point...
Page 546: Phasor Measurement Unit Communications
PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Ia Angle, Ib Angle, Ic Angle, Ig Angle Range: –5.00 to 5.00° in steps of 0.05 Default: 0.00° These settings recognize applications with protection class voltage and current sources, and allow the user to calibrate each channel (ground current and phase A, B, and C currents) individually to offset errors introduced by VTs, CTs, and cabling.
Page 547 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Figure 467: Phasor Measurement Unit communications configuration The following settings are available for the communication port on each PMU. Type Range: None, Network Default: None This setting specifies the first communication port for transmission of the PMU data. The three ports are configured under individual menus.
Page 548 PHS-1 Name, PHS-2 Name, PHS-3 Name,..., PHS-14 Name Range: 16 alphanumeric characters Default: GE-UR+PMU1-V1, GE-UR+PMU1-V2, GE-UR-PMU1+V3,..., GE-UR+PMU1-V14 These settings allow for custom naming of the synchrophasor channels. Sixteen- character ASCII strings are allowed as in the CHNAM field of the configuration frame.
Page 549: Phasor Measurement Unit Triggering
CHAPTER 11: METERING PHASOR MEASUREMENT UNIT D-CH-1 Normal State, D-CH-2 Normal State, D-CH-3 Normal State,..., D-CH-16 Normal State Range: On, Off Default: Off These settings allow for specifying a normal state for each digital channel. These states are transmitted in configuration frames to the data concentrator. Phasor Measurement Unit triggering Each logical PMU contains five triggering mechanisms to facilitate triggering of the associated PMU recorder and cross-triggering of other PMUs.
Page 550 PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Frequency triggering The trigger responds to the frequency signal of the Phasor Measurement Unit source. The frequency is calculated from phase voltages, auxiliary voltage, phase currents, or ground Plus current, in this hierarchy, depending on the source configuration as per D90 standards.
Page 551 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Block Range: any metering logic operand or shared operand Default: Off Assertion of the operand assigned to this setting blocks operation of the PMU frequency triggering function. Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of PMU frequency triggering events in the sequence of events recorder.
Page 552 PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the PMU voltage triggering function. Low Voltage Range: 0.250 to 1.250 pu in steps of 0.001 Default: 0.800 pu This setting specifies the low threshold for the abnormal voltage trigger, in per-unit values of the PMU source.
Page 553 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Figure 473: Voltage triggering logic Current triggering This Phasor Measurement Unit current triggering responds to elevated current. The trigger responds to the phase current signal of the PMU source. All current channel (A, B, and C) are processed independently and can trigger the recorder.
Page 554 PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Dropout Time Range: 0.00 to 600.00 seconds in steps of 0.01 Default: 1.00 seconds This setting is used to extend the trigger after the situation returns to normal. This setting is of particular importance when using the recorder in the forced mode (recording as long as the triggering condition is asserted).
Page 555 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Figure 476: Power triggering configuration settings The following settings are available for each PMU. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the PMU power triggering function. Active Range: 0.250 to 3.000 pu in steps of 0.001 Default: 1.250 pu This setting specifies the pickup threshold for the active power of the source.
Page 556 PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Dropout Time Range: 0.00 to 600.00 seconds in steps of 0.01 Default: 1.00 seconds This setting is used to extend the trigger after the situation returns to normal. This setting is of importance when using the recorder in the forced mode (recording as long as the triggering condition is asserted).
Page 557 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT The following settings are available for each PMU. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the PMU frequency rate of change triggering function. Raise Range: 0.10 to 15.00 Hz/s in steps of 0.01 Default: 0.25 Hz/s This setting specifies the pickup threshold for the rate of change of frequency in the rising direction (positive df/dt).
Page 558: Phasor Measurement Unit Recording
PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Figure 479: Frequency rate of change triggering logic Phasor Measurement Unit recording Each logical Phasor Measurement Unit is associated with a recorder. The triggering condition is programmed via the Settings > Metering > Phasor Measurement Unit > Triggering menu.
Page 559 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Figure 481: Phasor Measurement Unit recording configuration settings The following settings are available for each PMU. Recording Rate Range: 1, 2, 5, 10, 12, 15, 20, 25, 30, 50, or 60 times per second Default: 10 times per second This setting specifies the recording rate for the record content.
Page 560 PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Trigger Mode Range: Automatic Overwrite, Protected Default: Automatic Overwrite This setting specifies what happens when the recorder uses its entire available memory storage. If set to “Automatic Overwrite,” the last record is erased to facilitate new recording, when triggered.
Page 561 Rec PHS-1 Name, Rec PHS-2 Name, Rec PHS-3 Name,..., Rec PHS-14 Name Range: 16 character ASCII string Default: GE-UR+PMU-PHS1, GE-UR+PMU-PHS2, GE-UR+PMU-PHS3,..., GE-UR+PMU-PHS14 These settings allow for custom naming of the synchrophasor channels. Sixteen- character ASCII strings are allowed as in the CHNAM field of the configuration frame.
Page 562: Phasor Measurement Unit Reporting Over Network
PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Phasor Measurement Unit reporting over network The Phasor Measurement Unit Ethernet connection works simultaneously with other communication means over Ethernet. The network reporting feature is programmed via the Settings > Metering > Phasor Measurement Unit > Reporting Over Network menu. Figure 484: Phasor Measurement Unit reporting over network configuration settings The following settings are available for each PMU.
Page 563: Phasor Measurement Unit One-Shot
CHAPTER 11: METERING PHASOR MEASUREMENT UNIT PDC Control Range: Enabled, Disabled Default: Disabled The synchrophasor standard allows for user-defined controls originating at the PDC, to be executed on the PMU. The control is accomplished via an extended command frame. The relay decodes the first word of the extended field, EXTFRAME, to drive 16 dedicated FlexLogic operands: (from the least significant bit) to PDC NETWORK CNTRL 1...
Page 564 PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the PMU one-shot feature. Sequence Number Range: 0 to nominal frequency – 1, in steps of 1 Default: 1 When the match the Device Date Device Time PMU One-Shot Date...
Page 565 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Device Time Range: time in HH:MM:SS format Default: 00:00:00 Plus This value reflects the time programmed in the D90 . This time cannot be modified from this window. PMU One-Shot Date Range: date in MM/DD/YYYY format Default: 01/01/2007 Plus When the PMU unit one-shot feature is enabled, the D90...
Page 566: Data Logger
DATA LOGGER CHAPTER 11: METERING Figure 487: Testing synchrophasor measurement accuracy Collecting synchronized measurements ad hoc The Phasor Measurement Unit one-shot feature can be used for ad hoc collection of synchronized measurements in the network. Two or more PMUs can be pre-scheduled to freeze their measurements at the same time.
Page 567 CHAPTER 11: METERING DATA LOGGER Figure 488: Data logger configuration settings The following settings are available for the data logger. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the data logger. Block Range: any metering logic operand or shared operand Default: OFF Assertion of the operand assigned to this setting blocks data logger functionality.
Page 568: Data Logger Channel Configuration
DATA LOGGER CHAPTER 11: METERING Figure 489: Data logger logic Data logger channel configuration Select the Settings > Metering > Data Logger > Channel Configuration menu to open the data logger configuration window. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 569 CHAPTER 11: METERING DATA LOGGER Figure 490: Data logger channel configuration settings The following settings are available for all 16 data logger channels. Signal Range: any FlexAnalog parameter Default: Off This setting selects the metering value to be recorded for the data logger channel. Name Range: up to 12 alphanumeric characters Default: Channel 1...
Page 570: Metered Values
METERED VALUES CHAPTER 11: METERING High Alarm Pickup, Low Alarm Pickup, High-High Alarm Pickup, Low-Low Alarm Pickup Range: –90.00 to 90.00 pu in steps of 0.01 Default: 1.00 pu These settings specify the pickup thresholds for the alarm in per-unit values. A fixed hysteresis of 3% is applied.
Page 571 CHAPTER 11: METERING METERED VALUES Figure 491: Flow direction of signed values for watts and vars Plus All phasors calculated by the D90 and used for protection, control, and metering functions are rotating phasors that maintain the correct phase angle relationships with each other at all times.
Page 572 METERED VALUES CHAPTER 11: METERING For display and oscillography purposes, all phasor angles in a given device are referred to an AC input channel pre-selected by the setting in the Frequency and Phase Reference Settings > Protection > Power System > Frequency menu. This setting defines a particular AC signal source to be used as the reference.
Page 573 CHAPTER 11: METERING METERED VALUES The following voltages and currents are measured for wye-connected instrument transformers in the ACB phase rotation: Eq. 57 Eq. 58 Eq. 59 The following voltages and currents are measured for delta-connected instrument transformers in the ABC phase rotation. The zero-sequence voltage (V_0) is not measurable under the delta connection of instrument transformers and is defaulted to zero.
Page 574: Phase Current Metering
METERED VALUES CHAPTER 11: METERING can be chosen as a reference. It is important to remember that displayed values are always referenced as to the voltage specified by the Frequency and Phase Reference setting. Eq. 67 Eq. 68 The figure illustrates the examples. Figure 493: Measurement convention for symmetrical components Phase current metering Select the Actual Values >...
Page 575 CHAPTER 11: METERING METERED VALUES Figure 494: Phase current metering window The following actual values display for each source. Name Range: up to 20 alphanumeric characters This value displays the user-programmed name for each source. Phasors Clicking the View button for this value allows the user to configure and display a graphical representation of selected current and voltage phasors.
Page 576: Ground Current Metering
METERED VALUES CHAPTER 11: METERING Ground current metering Select the Actual Values > Metering > Ground Current menu to open the metered ground current window. Figure 495: Ground current metering window The following actual values display for each applicable source. Name Range: up to 20 alphanumeric characters This value displays the user-programmed name for each source.
Page 577: Auxiliary Voltage Metering
CHAPTER 11: METERING METERED VALUES Name Range: up to 20 alphanumeric characters This value displays the user-programmed name for each source. Phasors Clicking the View button for this value allows the user to configure and display a graphical representation of selected current and voltage phasors. For details, see Observing current and voltage phasors on page 571.
Page 578: Power Metering
METERED VALUES CHAPTER 11: METERING Figure 497: Auxiliary voltage metering window The following actual values display for each applicable source. Name Range: up to 20 alphanumeric characters This value displays the user-programmed name for each source. Phasors Clicking the View button for this value allows the user to configure and display a graphical representation of selected current and voltage phasors.
Page 579: Energy Metering
CHAPTER 11: METERING METERED VALUES The following actual values display for each applicable source. Name Range: up to 20 alphanumeric characters This value displays the user-programmed name for each source. Three Phase Real Power, Phase A Real Power, Phase B Real Power, Phase C Real Power Range: –1000000000.000 to 1000000000.000 W in steps of 0.001 These actual values display the metered real power for phase A, B, and C, as well as the three-phase real power, for each applicable source.
Page 580: Frequency Metering
METERED VALUES CHAPTER 11: METERING Positive varhour, Negative varhour Range: 0.000 to 1000000000000.000 varh in steps of 0.001 These actual values display the metered reactive energy for each applicable source. Frequency metering Select the Actual Values > Metering > Frequency menu to open the metered frequency window.
Page 581: Clearing Metered Values
CHAPTER 11: METERING OBSERVING CURRENT AND VOLTAGE PHASORS Clearing metered values Select the Actual Values > Metering > Commands menu to open the metering commands menu. The commands allow the user to clear accumulated metering values. Figure 502: Metering commands window The following commands are available.
Page 582 OBSERVING CURRENT AND VOLTAGE PHASORS CHAPTER 11: METERING Figure 503: Example of phasor configuration window with three phasor graphs The following options are available to configure the phasor graphs. Component Range: None, Phasor Ia, Phasor Ib, Phasor Ic, Phasor In, Zero Seq I0, Positive Seq I1, Negative Seq I2, Phasor Ig, Phasor Igd, Phasor Vag, Phasor Vbg, Phasor Vcg, Phasor Vab, Phasor Vbc, Phasor Vca, Zero Seq V0, Positive Seq V1, Negative Seq V2, Phasor Vx (phasor options are available for each signal source)
Page 583: Using Shared Operands In Metering
CHAPTER 11: METERING USING SHARED OPERANDS IN METERING Map Phasor Sets Range: Show Graph, Phasor Set 1, Phasor Set 2, Phasor Set 3,..., Phasor Set 12 Default: This option selects the phasor sets to display on each of the six available phasor graphs. The “Show Graph”...
Page 584: Shared Metering Operands
USING SHARED OPERANDS IN METERING CHAPTER 11: METERING Figure 504: Default operand list by function The content of each operand list depends on the order code. The shared operands functionality expands upon this system. An output from any element Plus can be assigned as a shared operand within the EnerVista UR Setup software.
Page 585: Customizing The Metering Logic Operands
CHAPTER 11: METERING USING SHARED OPERANDS IN METERING Figure 505: Shared operands configuration window Plus The left side of this screen displays all D90 operands that are available to the metering function as shared operands. Select any operands from the other five primary features by clicking the >>...
Page 586: Metering Logic Operands
USING SHARED OPERANDS IN METERING CHAPTER 11: METERING Figure 506: User-configurable metering logic operands window Plus The left side of this screen displays all operands that are currently available to the D90 The metering logic operands are displayed by expanding the Metering entry. Each operand can be renamed with a user-specified value to provide additional information or match specific applications.
Page 587: Metering Flexanalog Parameters
CHAPTER 11: METERING METERING FLEXANALOG PARAMETERS PMU 1 POWER TRIGGER......Asserted when the overpower trigger of Phasor Measurement Unit 1 operates. PMU 1 ROCOF TRIGGER......Asserted when the rate of change of frequency trigger of Phasor Measurement Unit 1 operates. PMU 1 TRIGGERED........Asserted when the Phasor Measurement Unit 1 triggers. No events or targets are generated by this operand.
Page 588 METERING FLEXANALOG PARAMETERS CHAPTER 11: METERING PMU 1 Va Mag..........Metered phase A voltage magnitude for Phasor Measurement Unit 1 PMU 1 Va Ang..........Metered phase A voltage angle for Phasor Measurement Unit 1 PMU 1 Vb Mag..........Metered phase B voltage magnitude for Phasor Measurement Unit 1 PMU 1 Vb Ang..........Metered phase B voltage angle for Phasor Measurement Unit 1 PMU 1 Vc Mag..........Metered phase C voltage magnitude for Phasor Measurement...
Page 589 CHAPTER 11: METERING METERING FLEXANALOG PARAMETERS SRC 1 I2 Mag..........Metered negative-sequence current magnitude for source 1 SRC 2..............The analog parameters shown above are available for sources 2 and above. Power metering analog operands SRC 1 P............Metered three-phase real power for source 1 SRC 1 Pa............Metered phase A real power for source 1 SRC 1 Pb............Metered phase B real power for source 1 SRC 1 Pc ............Metered phase C real power for source 1...
Page 590 METERING FLEXANALOG PARAMETERS CHAPTER 11: METERING SRC 1 Vx RMS..........Metered RMS auxiliary voltage for source 1 SRC 1 Vx Angle..........Metered auxiliary voltage angle for source 1 SRC 1 Vx Mag ..........Metered auxiliary voltage magnitude for source 1 SRC 1 V0 Angle..........Metered zero-sequence voltage angle for source 1 SRC 1 V0 Mag ..........Metered zero-sequence voltage magnitude for source 1 SRC 1 V1 Angle..........Metered positive-sequence voltage angle for source 1 SRC 1 V1 Mag ..........Metered positive-sequence voltage magnitude for source 1...
Page 591: Local Interface
Plus Line Distance Protection System Chapter 12: Local interface Local interface Plus This section outlines how to program the D90 local interface features. Local interface overview Plus The front panel of the D90 provides a color LCD annunciator alarm panel with an optional second LCD display for human-machine interface (HMI) functions that include user-configurable metering and control pages, access to the digital fault recorder, physical input/output status, and equipment maintenance functions.
Page 592: Annunciator Panel
ANNUNCIATOR PANEL CHAPTER 12: LOCAL INTERFACE Annunciator panel The annunciator indicates the status of system alarm points and actual values. It displays self-test messages and product information for the unit. Annunciator operation The annunciator supports three types of alarms: self-reset, latched, and acknowledgeable. Each location in an annunciator display page can be configured to be one of the three alarm types and can also display an optional metered value.
Page 593: Annunciator Configuration
CHAPTER 12: LOCAL INTERFACE ANNUNCIATOR PANEL Figure 509: Annunciator alarm sequence The table outlines annunciator states. Table 41: Acknowledgeable alarm states Sequence (initial Process (status) Pushbutton Sequence (final Visual indication state) (input) state) Normal Normal Normal Abnormal Alarm Fast flash Alarm Normal Alarm...
Page 594 ANNUNCIATOR PANEL CHAPTER 12: LOCAL INTERFACE Figure 510: Annunciator configuration settings The following settings are available. The setting descriptions apply to all 288 alarms, with different default values. Clear Latched Range: any FlexLogic operand or shared operand Default: OFF This setting allows the user to designate a FlexLogic operand to clear all latched alarms when the operand transitions to an active state.
Page 595 CHAPTER 12: LOCAL INTERFACE ANNUNCIATOR PANEL Alarm Type Range: Acknowledgeable, Latched, Self-Reset Default: Acknowledgeable This setting specifies the alarm type. Self-reset alarms track the state of the corresponding input operand. Latched alarms can be reset using the Ack/Reset button at the bottom of the display. Acknowledgeable alarms follow the state transitions listed in the previous section.
Page 596 ANNUNCIATOR PANEL CHAPTER 12: LOCAL INTERFACE programmable pushbutton or selector switch button being activated, a new fault report being triggered, selection of the autorecloser in the single line diagram, or toggling of the local/remote status. Figure 512: Annunciator navigation window If the Use Default check box is selected and the Default Page is set to “None,”...
Page 597 CHAPTER 12: LOCAL INTERFACE ANNUNCIATOR PANEL Figure 513: Metering value properties window The following parameters are available. Parameter Range: any FlexAnalog parameter Default: Digital Counter 1 Value This setting selects a FlexAnalog parameter that specifies the metered value to display in the annunciator alarm.
Page 598: Mimic Diagram Editor
MIMIC DIAGRAM EDITOR CHAPTER 12: LOCAL INTERFACE Display in Line Range: 1, 2, 3 Default: 1 This setting specifies the line in the annunciator alarm to display the metered value. It can be displayed in lines 1, 2, or 3 if the page layout is 3 × 4 or 4 × 6. For 6 × 8 layouts, it can be displayed in lines 1 or 2.
Page 599: Dynamic Symbols
CHAPTER 12: LOCAL INTERFACE MIMIC DIAGRAM EDITOR Figure 515: Mimic diagram components library The following functions are available for the mimic diagram editor: • Circuit breakers • Disconnect and earthing switches • Busbars • Transformers • Capacitor banks • Reactors •...
Page 600: Static Symbols
MIMIC DIAGRAM EDITOR CHAPTER 12: LOCAL INTERFACE Figure 516: Mimic diagram editor dynamic symbols A maximum of 10 dynamic components is allowed for each mimic diagram. When a dynamic symbol is selected and added to the diagram, a window appears to configure the device.
Page 601: Metering Blocks
CHAPTER 12: LOCAL INTERFACE MIMIC DIAGRAM EDITOR Figure 518: Mimic diagram editor static symbols For more information on these symbols, see the ANSI/IEEE 315A and IEC 617 standards. There is no limit on the number of static symbols per screen, provided that they fit within the screen dimensions.
Page 602 MIMIC DIAGRAM EDITOR CHAPTER 12: LOCAL INTERFACE Figure 520: Mimic diagram metering block symbol The properties of a metering block can be configured by right-clicking the box and selecting Properties to open the Metering Properties configuration window. Figure 521: Metering properties configuration window The following parameters are available.
Page 603: Text Blocks
CHAPTER 12: LOCAL INTERFACE MIMIC DIAGRAM EDITOR Scale Factor Range: G (Giga), M (Mega), k (kilo), None Default: None This setting allows the user to select a scaling factor for the metering units value. The range is restricted to correspond to the selected analog value parameter. Multiplier Range: dependent on the selected analog value Default: None...
Page 604: Pre-Configured Mimic Diagrams
MIMIC DIAGRAM EDITOR CHAPTER 12: LOCAL INTERFACE • Overview mode — Provides a preview of how the mimic diagram appears on the overview screen of the front panel interface • Control mode — Provides a preview of how the mimic diagram appears on the control screen of the front panel interface These modes allow the user to ensure that the mimic diagram displays appropriately in all display screens.
Page 605 CHAPTER 12: LOCAL INTERFACE MIMIC DIAGRAM EDITOR Figure 524: Pre-configured mimic diagram 1 (breaker-and-a-half scheme) Figure 525: Pre-configured mimic diagram 2 (breaker-and-a-half scheme with breaker disconnects) Figure 526: Pre-configured mimic diagram 3 (breaker-and-a-half scheme, with breaker and line disconnects) Figure 527: Pre-configured mimic diagram 4 (breaker-and-a-half scheme, with breaker, PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 606 MIMIC DIAGRAM EDITOR CHAPTER 12: LOCAL INTERFACE line, and ground disconnects) Figure 528: Pre-configured mimic diagram 5 (breaker-and-a-half scheme with line disconnect) Figure 529: Pre-configured mimic diagram 6 (breaker-and-a-half scheme with line and ground disconnects) PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 607 CHAPTER 12: LOCAL INTERFACE MIMIC DIAGRAM EDITOR Figure 530: Pre-configured mimic diagram 7 (double-bus bypass scheme 1) Figure 531: Pre-configured mimic diagram 8 (double-bus bypass scheme 2) Figure 532: Pre-configured mimic diagram 9 (double-bus bypass scheme with line and ground disconnects) PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 608: Metering Summary Editor
METERING SUMMARY EDITOR CHAPTER 12: LOCAL INTERFACE Figure 533: Pre-configured mimic diagram 10 (single-bus scheme) Figure 534: Pre-configured mimic diagram 11 (single-bus scheme with line disconnect) Figure 535: Pre-configured mimic diagram 12 (single-bus scheme with line and ground disconnects) Metering summary editor Select the Settings >...
Page 609 CHAPTER 12: LOCAL INTERFACE METERING SUMMARY EDITOR Figure 536: Metering summary editor window A click of the left mouse button in a metering location opens the following window. You enter header text of a selected font size and color, or select a metered quantity from the drop-down list.
Page 610 METERING SUMMARY EDITOR CHAPTER 12: LOCAL INTERFACE Figure 537: Metering configuration window Text Range: up to 20 alphanumeric characters Default: --- This setting defines the selected metering cell as a text box. These are used typically as headings. Specify up to 10 alphanumeric characters. Parameter Range: any FlexAnalog parameter Default: Digital Counter 1 Value...
Page 611: User-Programmable Pushbuttons
CHAPTER 12: LOCAL INTERFACE USER-PROGRAMMABLE PUSHBUTTONS Number of Integers Range: 1 to 6 in steps of 1 Default: 1 This setting specifies the number of integers in the displayed metering cell. It can be used to provide for leading character spacing of the resultant display value. Number of Decimals Range: 1 to 6 in steps of 1 Default: 3...
Page 612: User-Programmable Pushbutton Operation
USER-PROGRAMMABLE PUSHBUTTONS CHAPTER 12: LOCAL INTERFACE User-programmable pushbutton operation User-programmable pushbuttons provide a simple and error-free way to enter digital state (on, off) information. The digital state can be entered locally (by directly pressing the front panel pushbutton) or remotely (via operands) into logic equations, protection elements, and control elements.
Page 613: User-Programmable Pushbutton Settings
CHAPTER 12: LOCAL INTERFACE USER-PROGRAMMABLE PUSHBUTTONS User-programmable pushbutton settings Select the Settings > Local HMI > User-Programmable Pushbuttons menu to open the user-programmable pushbuttons settings window. Figure 538: User-programmable pushbutton configuration settings The following settings are available for each user-programmable pushbutton. Function Range: Disabled, Latched, Self-Reset Default: Disabled...
Page 614 USER-PROGRAMMABLE PUSHBUTTONS CHAPTER 12: LOCAL INTERFACE Autoreset Range: Disabled, Enabled Default: Disabled This setting enables the user-programmable pushbutton autoreset feature. This setting applies when the pushbutton is in latched mode. Autoreset Delay Range: 0.2 to 600.0 seconds in steps of 0.1 Default: 1.0 seconds This setting specifies the time delay for automatic reset of the pushbutton when in latched mode.
Page 615 CHAPTER 12: LOCAL INTERFACE USER-PROGRAMMABLE PUSHBUTTONS Figure 539: User-programmable pushbutton logic, sheet 1 of 2 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 616: User-Programmable Pushbutton Editor
USER-PROGRAMMABLE PUSHBUTTONS CHAPTER 12: LOCAL INTERFACE Figure 540: User-programmable pushbutton logic, sheet 2 of 2 User-programmable pushbutton editor Select the Settings > Local HMI > User-Programmable Pushbuttons Editor menu to open the user-programmable pushbuttons editor window. Figure 541: User-programmable pushbuttons editor settings Click the Configure button to access the settings.
Page 617 CHAPTER 12: LOCAL INTERFACE USER-PROGRAMMABLE PUSHBUTTONS Figure 542: Pushbutton configuration window The following settings are available. Button Name Range: up to 20 alphanumeric characters Default: --- This setting allows the user to assign a pushbutton or selector switch name that appears on the user-programmable pushbutton window and on the display page when the corresponding pushbutton element or selector switch element is disabled.
Page 618 USER-PROGRAMMABLE PUSHBUTTONS CHAPTER 12: LOCAL INTERFACE Choose Selector Range: 1 to 10 in steps of 1 Default: 1 This setting selects the selector switch number to associate with the current control key. This setting is available when the is “Selector Switch.” Button Type State 1 Text, State 2 Text,..., State 10 Text Range: up to 19 alphanumeric characters...
Page 619: Security
Plus Line Distance Protection System Chapter 13: Security Security Plus This section outlines how to program the D90 security features. Password security It is recommended that passwords be programmed for each security level and assigned to specific personnel. There are two password security access levels: command and setting. The command access level restricts the user from making any settings changes, but allows the user to perform the following operations: •...
Page 620: Password Security Operation
PASSWORD SECURITY CHAPTER 13: SECURITY When entering a settings or command password via Ethernet or the serial USB interface, you must enter the corresponding password level shown in the following table. Table 42: Required password levels for various connection types Connection type Password required Front panel USB...
Page 621 CHAPTER 13: SECURITY PASSWORD SECURITY Local Command Password Range: up to 12 visible ASCII characters (see restrictions outlined) Default: null The value of the local command password is specified here. For the password to be successfully entered, the values in the Enter New Password Confirm New Password fields must be identical.
Page 622 PASSWORD SECURITY CHAPTER 13: SECURITY Invalid Password Attempts Range: 2 to 5 in steps of 1 Default: 3 This setting specifies the number of times an incorrect password can be entered within a three-minute time span before lockout occurs and applies to both the setting and command passwords.
Page 623: Enervista Security Management System
EnerVista. It is disabled by default to allow access to the device immediately after installation. When security is disabled, all users have administrator access. GE recommends enabling the EnerVista security before placing the device in service. To enable the security system and require password use: Select the Security >...
Page 624: Add A New User
If you force password entry by using this feature, ensure that you know the Administrator NOTE: password. If you do not know the password and are locked out of the software, contact GE Digital Energy for the default password. Add a new user...
Page 625: Modify User Privileges
CHAPTER 13: SECURITY ENERVISTA SECURITY MANAGEMENT SYSTEM Enter a username in the User field. The username must be four to 20 characters in length. Select the user access rights by enabling the check box of one or more fields. Table 43: Access rights summary Field Description Delete Entry...
Page 626 ENERVISTA SECURITY MANAGEMENT SYSTEM CHAPTER 13: SECURITY Locate the username in the User field. Modify the user access rights by enabling or disabling one or more of the check boxes. Table 44: Access rights summary Field Description Delete Entry Deletes the user account when exiting the user management window Actual Values Allows the user to read actual values Settings...
Page 627: Testing
Plus Line Distance Protection System Chapter 14: Testing Testing Plus This section outlines the D90 testing features. Test mode Plus The D90 provides test settings to verify functionality using simulated conditions for contact inputs and outputs. To initiate test mode, the setting must be Test Mode Function “Enabled”...
Page 628: Force Contact Outputs
TEST MODE CHAPTER 14: TESTING Figure 544: Force contact inputs configuration settings The following settings are available. Test Mode Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the test mode functionality for contact inputs. Test Mode Initiate Range: any FlexLogic operand Default: ON The test mode initiates when the operand assigned to this setting is logic 1.
Page 629: Self-Tests
CHAPTER 14: TESTING SELF-TESTS Figure 545: Force contact outputs configuration settings The following settings are available. Test Mode Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the test mode functionality for contact outputs. Test Mode Initiate Range: any FlexLogic operand Default: ON The test mode initiates when the operand assigned to this setting is logic 1.
Page 630: Self-Test Error Messages
Description: There a firmware mismatch between the AC card in the indicated slot and the CPU. Severity: Protection is not available, and relay is not operational. If either message appears, contact GE Digital Energy. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 631 Description: The AC module in the indicated slot is not properly calibrated. Severity: Device is temporarily out-of-service. If either message appears, reset the alarm. If the alarm recurs, contact GE Digital Energy. AC SLOT F TROUBLE AC SLOT J TROUBLE Description: The AC module in the indicated slot is not operational.
Page 632 IO SLOT K NOT CALIBRATED Description: The input/output module in the indicated slot is not properly calibrated. Severity: Device is temporarily out-of-service. If any of these messages appear, reset the alarm. If the alarm recurs, contact GE Digital Energy. IO SLOT E TROUBLE...
Page 633 CHAPTER 14: TESTING SELF-TESTS The minor self-test error messages are indicated in yellow on the annunciator display and are described as follows. AC SLOT F HIGH TEMP AC SLOT J HIGH TEMP Description: The ambient temperature is outside the specifications for the AC card in the indicated slot.
Page 634 If this message appears, check that the voltage at the power supply input is within limits. If acceptable, check that the 48 volt supply is healthy. If not acceptable, contact GE Digital Energy. REMOTE DEVICES OFF Description: A remote device is specified in the configuration for GOOSE messaging but is not connected to the network.
Page 635: Self-Test Logic Operands
CHAPTER 14: TESTING SELF-TESTS SNTP ERROR FAILURE Description: The SNTP server is not responding. Severity: Protection is available. Timestamping of events can be inaccurate. If this message appears, check that the SNTP server is operational and configured correctly. Check for Ethernet LAN problems. UNDEFINED RESULT Description: An error has occurred during automation logic execution.
Page 636 SELF-TESTS CHAPTER 14: TESTING IO SLOT E TROUBLE........Asserted when the IO SLOT E TROUBLE self-test error message is issued. IO SLOT F FMW MSMTCH......Asserted when the IO SLOT F FIRMWARE MISMATCH self-test error message is issued. IO SLOT F NOT CAL ........Asserted when the IO SLOT F NOT CALIBRATED self-test error message is issued.
Page 637: Theory Of Operation
Plus Line Distance Protection System Chapter 15: Theory of operation Theory of operation This chapter outlines advanced information on operation. Distance elements The distance element is composed of two separate algorithms. The first is a conventional frequency domain (phasor) algorithm based on the UR-series D60 implementation. The second is a time domain algorithm that achieves sub-cycle operating times.
Page 638: Distance Element Time Domain Algorithm
DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION • Positive-sequence voltage is between 0.8 and 1.2 pu • Source frequency differs from tracking frequency by less than 0.5 Hz • Source frequency differs from nominal frequency by less than 5.5 Hz •...
Page 639: Distance Supervision
CHAPTER 15: THEORY OF OPERATION DISTANCE ELEMENTS The voltage signals are pre-filtered using a special digital filter designed to cope with CVT transients. This patented filter combines filtering and memory actions enabling the relay to cope with CVT noise under high source impedance ratios (SIRs). The filter controls underestimation of the fault voltage magnitude to less than 1% of the nominal and prevents certain phase angle anomalies that can be encountered under heavy CVT noise and high SIRs.
Page 640: Distance Characteristics
DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION Distance characteristics The relay shapes its distance characteristics using phase angle comparators and estimated voltage and current phasors. The following distance characteristic definitions pertain to all phase and ground distance functions: Phase A, B, and C current phasors Ground current from a parallel line Phase A to ground, phase B to ground, and phase C to ground voltage phasors Positive-sequence phasor of ( ) term derived from the phase quantities...
Page 641 CHAPTER 15: THEORY OF OPERATION DISTANCE ELEMENTS Element Value 1 Value 2 A ground element × Z + I_0 × K × Z + I × K × Z – V B ground element × Z + I_0 × K ×...
Page 642 DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION If the mho characteristic is selected, the limit angle of the comparator is adjustable concurrently with the limit angle of the mho characteristic, resulting in a tent shape complementing the lens characteristic being effectively applied. Quadrilateral reactance characteristic for directional applications The quadrilateral reactance characteristic is achieved by checking the angle between the two values for the various phase and ground distance elements shown in the table.
Page 643 CHAPTER 15: THEORY OF OPERATION DISTANCE ELEMENTS Element Value 1 Value 2 A ground element I_0 × Z _2 × Z B ground element I_0 × Z _2 × Z C ground element I_0 × Z _2 × Z The characteristic and limit angles of the directional comparator are adjusted independently from the mho and reactance comparators.
Page 644 DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION The limit angle of the comparator is not adjustable and equals 50°. The fault type characteristic is intended to block ground distance elements during double-line-to-ground faults. Zero-sequence directional characteristic The extra zero-sequence characteristic is achieved by checking the angle between the two values for the elements shown in the table.
Page 645 CHAPTER 15: THEORY OF OPERATION DISTANCE ELEMENTS Characteristic Comparator inputs Limit angle Input 1 Input 2 Zero-sequence I_0 × Z –V_0 90° (zones 2 and 3 only; removed during open pole conditions) Table 15-13: Directional quadrilateral phase distance functions Characteristic Comparator inputs Limit angle Input 1...
Page 646: Memory Polarization
DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION Table 15-18: Non-directional quadrilateral ground distance functions Characteristic Comparator inputs Limit angle Input 1 Input 2 jΘ jΘ Forward reactance I × Z – V j × I_0 × e or j × I_2 × e Comparator limit jΘ...
Page 647: Distance Elements Analysis
CHAPTER 15: THEORY OF OPERATION DISTANCE ELEMENTS Figure 552: Dynamic shift of the memory-polarized quadrilateral characteristic Mutual zero-sequence compensation can raise concerns regarding directional integrity on reverse faults in the situation when the relay gets overcompensated. This problem does not Plus affect the D90 because its ground distance elements use zero-sequence and negative-...
Page 648 DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION Figure 553: Typical ground distance settings window Plus Assume the following signals are injected into the D90 Eq. 69 Plus Based on these signals and the programmed settings, the D90 calculates the following values: Eq.
Page 649 CHAPTER 15: THEORY OF OPERATION DISTANCE ELEMENTS Mho phase A to ground element analysis, before memory expires Before the memory expires, the following values are calculated for the mho phase A to ground distance element: Eq. 72 The ground distance element checks for the following conditions for overcurrent supervision and the difference angles.
Page 650 DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION Plus When memory expires, the D90 uses the actual voltage for polarization. The following values are calculated for the mho phase A to ground distance element: Eq. 74 The ground distance element checks for the following conditions for overcurrent supervision and the difference angles.
Page 651 CHAPTER 15: THEORY OF OPERATION DISTANCE ELEMENTS Table 20: Mho phase AB element conditions Parameter Condition Supervision Overcurrent supervision | (I – I ) / √3 | > | ∠((I )) – ∠((V Comparator Limit Mho difference angle – I ) ×...
Page 652: Phase Distance Applied To Power Transformers
PHASE DISTANCE APPLIED TO POWER TRANSFORMERS CHAPTER 15: THEORY OF OPERATION The results are shown in the following table. Table 23: Quadrilateral phase A to ground element analysis Parameter Calculation Requirement Condition met Overcurrent supervision 3 × 1.37 A = 4.09 A >...
Page 653 CHAPTER 15: THEORY OF OPERATION PHASE DISTANCE APPLIED TO POWER TRANSFORMERS Figure 554: Applications of the phase distance transformer settings In the following tables, the suffix “_21P” indicates current or voltage inputs to the phase NOTE: distance (ANSI 21P) element. Table 24: Phase distance input signals for delta-wye transformers Transformer Loop...
Page 654 PHASE DISTANCE APPLIED TO POWER TRANSFORMERS CHAPTER 15: THEORY OF OPERATION Transformer Loop Current transformation Voltage transformation connection _21P - _21P _21P - _21P _21P - _21P _21P - _21P _21P - _21P _21P - _21P _21P - _21P _21P - _21P _21P - _21P...
Page 655: Example Of System With Power Transformers
CHAPTER 15: THEORY OF OPERATION PHASE DISTANCE APPLIED TO POWER TRANSFORMERS Transformer Loop Current transformation Voltage transformation connection _21P _21P = _21P _21P = _21P _21P = _21P - _21P _21P _21P - _21P _21P - _21P = _21P _21P _21P = _21P _21P =...
Page 656 PHASE DISTANCE APPLIED TO POWER TRANSFORMERS CHAPTER 15: THEORY OF OPERATION Figure 555: Example system configuration Plus The D90 input signals at point X are shown in the following table. Table 26: Input signals at point X for example system with power transformers Input Primary Secondary...
Page 657: Ground Directional Overcurrent Theory
CHAPTER 15: THEORY OF OPERATION GROUND DIRECTIONAL OVERCURRENT THEORY Consequently, the following signals are applied to the phase AB distance element: Eq. 77 Eq. 78 This results in the following apparent impedance: Eq. 79 The apparent impedance calculated in the equation is a correct measure of the distance from the VT location to the fault.
Page 658: Ground Directional Overcurrent Example
GROUND DIRECTIONAL OVERCURRENT THEORY CHAPTER 15: THEORY OF OPERATION To ensure operation of the element under such circumstances, the angle comparator uses a polarizing voltage augmented by the negative-sequence current as shown in the following equations. For the forward-looking element: Eq.
Page 659: Series Compensated Lines
CHAPTER 15: THEORY OF OPERATION SERIES COMPENSATED LINES Series compensated lines Faults on or in close vicinity to series compensated lines can create problems for distance protection. Voltage or current inversion can lead to false direction discrimination by directional elements. This can potentially include both a failure to operate on a forward in-zone fault as well as misoperation on a reverse fault.
Page 660: Dynamic Reach Control
SERIES COMPENSATED LINES CHAPTER 15: THEORY OF OPERATION Dynamic reach control The problem of steady-state overreaching due to the negative reactance of the series Plus capacitors can be addressed in the D90 in a traditional way by shortening the reach of an underreaching distance element to the net inductive reactance of the line between the potential source and the far end busbars.
Page 661 CHAPTER 15: THEORY OF OPERATION SERIES COMPENSATED LINES Figure 558: Dynamic reach, low-current external fault The following figure shows a high-current external fault. The air gaps or MOVs conduct the majority of the fault current and neither steady-state nor transient overreach takes place. The relay does not reduce its reach because it is not necessary.
Page 662: Single-Pole Tripping
SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION Figure 560: Dynamic reach, high-current internal fault Single-pole tripping Plus Single-pole operations make use of many D90 features. At a minimum, the trip output, recloser, breaker control, open pole detector, and phase selector must be fully programmed and in-service, and either protection elements or digital inputs representing fault detection must be available for successful operation.
Page 663 CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING Figure 561: Single-pole operation The trip output element receives requests for single-pole and three-pole trips and three- pole reclose initiation. It then processes these requests to generate outputs that are used to perform the following functions: •...
Page 664: Slg Fault Scenario For Single-Pole Tripping
SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION : “GND DIST Z1 OP” Trip 1-Pole Input 1 : “PHS DIST Z1 OP” Trip 1-Pole Input 2 By default the POTT scheme issues a single-pole trip. It is assumed that when tripping three poles both the zone 1 and the POTT initiate three-pole reclosing.
Page 665: Slg Fault Evolving Into An Llg Fault Scenario For Single-Pole Tripping
CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING zone 1 operate and zone 2 pickup operands that were picked up reset immediately. The BG, CG, and BC distance elements remain operational guarding the line against evolving faults. As zone 2 or negative-sequence directional elements pick up due to the fault, the permission to trip is keyed to the remote end.
Page 666: Phase Selection
SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION reset. If the zone 1 BG element picks up, or the zone 2 BG element picks up resulting in operation of the POTT scheme, no trip command is issued until the AR FORCE 3-P TRIP asserted.
Page 667: Communications Channels For Pilot-Aided Schemes
CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING When the trip command is issued by the trip output logic (TRIP 1-POLE TRIP 3-POLE operands asserted) and during open pole conditions (OPEN POLE OP operand asserted), the phase selector resets all of its output operands and ignores any subsequent operations of the disturbance detector.
Page 668 SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION Single-bit channels Single-bit communication channels for pilot-aided schemes use the RX1 and TX1 operands for each scheme. The tables show how fault data is coded. Table 28: Permissive scheme transmit codes for single-bit channels Phase selector determination of fault type Bit pattern AG, BG, CG, ABG, BCG, CAG, AB, BC, CA, and 3P...
Page 669 CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING Table 33: Unblocking scheme trip table for single-bit channels Remote data Local data Bit pattern Remote determination Local determination of Trip output of fault type fault type LOG1 0 or 1 AG fault DCUB TRIP A 0 or 1 BG fault...
Page 670 SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION Remote data Local data Bit pattern Remote determination of Local determination of fault Trip output fault type type AG, BC, or BCG TRIP PHASE B CG, AB, ABG, 3P, or CG, BC, BCG, CA, or CAG TRIP PHASE C unrecognized AG, BC, or BCG...
Page 671 CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING Remote data Local data Bit pattern Remote determination of Local determination of fault Trip output fault type type BG, CA, CAG BG, AB, ABG BC, BCG, 3P DCUB TRIP B BG, CA, CAG BG, AB, ABG BC, BCG, 3P DCUB TRIP B CG, AB, ABG, 3P,...
Page 672 SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION Table 41: Blocking scheme transmit codes for four-bit channels Phase selector determination of fault type Bit pattern Operands asserted STOP STOP STOP STOP AB, ABG, BC, BCG, CA, CAG, 3P, or unrecognized Table 42: Unblocking scheme transmit codes for four-bit channels Phase selector determination of fault type Bit pattern AB, ABG, BC, BCG, CA, CAG, 3P, or unrecognized...
Page 673 CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING Table 44: Blocking scheme trip table for four-bit channels Remote data Local data Bit pattern Remote Local determination Trip output determination of of fault type fault type Any while the INIT Trip as for single- signal was not bit channel established...
Page 674: Permissive Echo Signaling
SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION Remote data Local data Bit pattern Remote Local Trip output determination of determination of fault type fault type AG, AB, ABG, CA, DCUB TRIP B CAG, 3P, unrecognized DCUB TRIP B DCUB TRIP B DCUB TRIP B DCUB TRIP B MULTI-P...
Page 675: Pilot Scheme And Phase Selector Coordination
CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING used). The permissive echo is programmed as a one-shot logic. The echo is sent only once and then the echo logic locks out for a user-specified period. The duration of the echo pulse does not depend on the duration or shape of the received RX signal but is programmable with the setting.
Page 676: Cross-Country Fault Example
SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION This enhanced operation of the pilot-aided schemes is the reason to use a short pilot scheme priority time when setting the trip output logic. The timer forces the scheme to wait for a decision from the pilot scheme for a short period of time before accepting any local trip request.
Page 677 CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING Table 50: Trip table for cross-country fault example, four-bit channel Terminal Remote data Local data Bit pattern Remote Local Trip output determination of determination of fault type fault type TRIP PHASE A TRIP PHASE A PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 678 SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 679: Appendix
This section provides the warranty and revision history. Warranty For products shipped as of 1 October 2013, GE Digital Energy warrants most of its GE manufactured products for 10 years. For warranty details including any limitations and disclaimers, see the GE Digital Energy Terms and Conditions at http://gedigitalenergy.com/multilin/warranty.htm...
Page 680 REVISION HISTORY CHAPTER 16: APPENDIX Table 52: Major changes for document version F3 Page Change Updated design of Instruction Manual and Communications Guide by putting into new template Edited entire documents, minor restructuring to make more consistent with UR manuals Minor revisions to both Instruction Manual and Communications Guide, for example to Trip Output and Breaker Configuration logic diagrams Added Communications Overview section after Hardware Architecture section, from...
Page 681 Plus Line Distance Protection System Index Automation virtual analog outputs description ..................... 471 settings ....................471 AC modules Automation virtual inputs connections ..................... 47 description ..................... 461 description .................... 174 logic ......................462 Altitude ......................38 settings ....................461 Annunciator specifications ..................29 operation ..................76, 582 Automation virtual outputs...
Page 682 INDEX Auxiliary undervoltage Breaker interlocking logic ......................274 description .....................434 operands ....................416 logic ......................436 settings ....................273 operands ....................488 specifications ..................19 settings ....................434 specifications ..................30 Backwards compatible ..........60, 82, 92, 251 Bandwidth limitation settings Cautions ......................1 ............101 Certifications Battery monitor ..................
Page 683 INDEX Directional comparison blocking Equipment manager description .................... 305 description ..................... 493 logic ......................309 front panel interface ................75 operands ....................418 operands ....................503 settings ....................306 overview ....................493 Directional comparison unblocking Ethernet description .................... 309 actual values ................102, 103 logic ......................
Page 684 INDEX Front panel operation IEC 61850 ................70 actual values ............141, 142, 143, 144 DNA assignments ................122 GGIO1 settings ..................135 GGIO2 settings ..................135 GGIO1 settings ..................135 GGIO4 settings ..................136 GGIO2 settings ..................135 GGIO5 settings ..................138 GGIO4 settings ..................136 GSSE/GOOSE configuration ............115 GGIO5 settings ..................
Page 685 INDEX Metering logic Neutral time overcurrent operands ....168, 169, 427, 491, 504, 531, 576, 577, 625 description ..................... 243 Mimic diagram logic ....................245, 247 operands ....................421 overview ....................588 settings ....................244 settings ....................594 specifications ..................24 MMXU deadbands ................
Page 686 INDEX Phase overvoltage Power supply description .................... 268 connections .....................46 logic ......................269 specifications ..................35 operands ....................423 Power swing det ect settings ....................268 settings ....................214 specifications ..................27 Power swing detect Phase selector characteristic ..................212 operands ....................424 description ..................12, 211 specifications ..................27 operands ..................213, 426 Phase time overcurrent...
Page 687 INDEX Rear terminal layout Shared operands ................41 Redundancy automation ................... 472 ....................95 digital fault recorder ................. 530 Remote devices equipment manager ................ 501 description .................... 121 metering ....................574 settings ....................121 protection ....................401 Remote double-point status input operands .......
Page 688 INDEX Time overcurrent curves VT fuse failure definite time curve ................235 description .....................333 FlexCurv es .................... 235 logic ......................334 I2t curves ....................234 operands ....................427 IAC curves ....................233 settings ....................334 IEC curves ....................231 specifications ..................29 IEEE curves .................... 230 overview ....................

GE D90 Plus Instruction Manual

Safety Symbols and Definitions

For Further Assistance

2 PRODUCT Product Description

Order Codes

Specifications

3 Installation

Unpack and Inspect

Panel Cutouts

Wiring

Install Software

4 Front Panel Interface

Metering Menu

Control Menu

Digital Fault Recorder Menu

Equipment Manager Menu

Annunciator

1 Introduction

5 Enervista Software

SOFTWARE Settings Templates

Secure and Lock Flexlogic Equations

Settings File Traceability

6 COMMUNICATIONS Communications Overview

Network Settings

Modbus Communications

DNP Communications

IEC 60870-5-104 Communications

IEC 61850 Communications

Flexstates

Real-Time Clock

User-Programmable Self-Tests

Serial Port

Direct Inputs and Outputs

Teleprotection Inputs and Outputs

Inter-Relay Communications

Communication Logic Operands

Communication Flexanalog Parameters

7 PROTECTION Protection Overview

Power System

Grouped Protection Elements

Control Elements

Protection Inputs and Outputs

Protection Flexlogic

Protection Flexanalog Parameters

8 Automation

Breakers

Disconnects

Automation Control

Automation Inputs and Outputs

Automation Logic

Automation Flexanalog Parameters

9 Equipment Manager

Overview of Equipment Manager

Circuit Breaker Arcing Management

Battery Monitor

Using Shared Operands in Equipment Manager

Equipment Manager Flexanalog Parameters

10 Digital Fault Recorder

Sequence of Events Recorder

Fault Report

Transient Recorder

Disturbance Recorder

Using Shared Operands in Digital Fault Recorder

Digital Fault Recorder Flexanalog Parameters

11 Metering

Metering Source

Phasor Measurement Unit

Data Logger

Metered Values

Observing Current and Voltage Phasors

Using Shared Operands in Metering

Metering Flexanalog Parameters

12 Local Interface

Annunciator Panel

MIMIC Diagram Editor

Metering Summary Editor

User-Programmable Pushbuttons

13 Security

Password Security

Enervista Security Management System