Page 1 Grid Solutions Plus Line Distance Protection System Instruction Manual Product version: 1.8x GE publication code: 1601-9019-E5 (GEK-113248E) 1601-9019-E5...
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 GETTING STARTED Important procedures ....................1 Cautions and warnings..........................1 Inspection checklist............................1 Plus Introduction to the UR -series.................2 Hardware architecture ..........................3 Firmware architecture ..........................4 Communications overview ........................6 EnerVista software......................7 Software requirements..........................8 Installing the software ..........................8 Software access............................
Page 4 TABLE OF CONTENTS 3 INSTALLATION Physical installation.....................47 Dimensions ..............................47 Rear terminal layout ...........................48 Electrical installation ....................49 Typical wiring ..............................49 Dielectric strength ............................50 Main processor module ..........................51 Communications module.........................53 Power supply module..........................53 AC modules..............................54 Contact input and output modules .....................56 Inter-relay communication modules....................60 4 INTERFACES Front panel overview ....................67 Front panel interface operation......................68...
Page 5 TABLE OF CONTENTS GGIO1 status configuration......................... 129 GGIO2 control configuration ....................... 129 GGIO4 analog configuration ....................... 130 GGIO5 control configuration ....................... 132 Unbuffered report control configuration ..................133 Buffered report control configuration .................... 134 IEC 61850 actual values........................135 FlexStates........................138 FlexState settings .............................
Page 6 TABLE OF CONTENTS Breaker flashover............................369 Digital counters............................374 FlexCurves™ ..............................377 Protection inputs and outputs ................381 Protection virtual inputs.........................381 Protection virtual outputs ........................383 Contact input configuration.........................385 Contact outputs............................390 Direct inputs ..............................391 Direct outputs .............................393 Teleprotection inputs and outputs ....................394 Using shared operands in protection....................397 Protection FlexLogic™...
Page 7 TABLE OF CONTENTS 9 EQUIPMENT Overview of the equipment manager..............493 MANAGER Breaker management....................494 Circuit breaker arcing..........................494 Battery monitor ......................497 Indications and wiring..........................497 Battery monitor settings ........................498 Using shared operands in the equipment manager........... 500 Shared equipment manager operands ..................
Page 8 TABLE OF CONTENTS Using shared operands in metering ..............573 Shared metering operands ........................574 Customizing the metering logic operands..................575 Metering logic operands........................576 Metering FlexAnalog™ parameters ............... 577 12 LOCAL INTERFACE Local interface overview ..................581 Annunciator panel..................... 582 Annunciator operation ...........................582 Annunciator configuration ........................583 Mimic diagram editor ....................
Page 9 TABLE OF CONTENTS Dynamic reach control .......................... 650 Single-pole tripping....................652 SLG fault scenario for single-pole tripping ................... 654 SLG fault evolving into an LLG fault scenario for single-pole tripping ......655 Phase selection............................656 Communications channels for pilot-aided schemes............... 657 Permissive echo signaling ........................
Page 10 TABLE OF CONTENTS PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 11: Getting Started
Plus Line Distance Protection System Chapter 1: Getting started Getting started Plus Please read this section to help guide you through the initial setup of the D90 Line Distance Protection System. Important procedures It is highly recommended that the following sections are reviewed before placing the Plus in service.
Page 12: Introduction To The Ur Plus -Series
This new generation of equipment must also be easily incorporated into automation systems, at both the station and enterprise levels. The GE Multilin Advanced Universal Protection System Plus -series) has been developed to meet these goals.
Page 13: Hardware Architecture
Plus CHAPTER 1: GETTING STARTED INTRODUCTION TO THE UR -SERIES Plus The D90 is the sub-cycle distance protection and advanced automation controller for Plus the UR -series platform. Hardware architecture Plus The D90 is a microprocessor-based device. It has a modular design consisting of a chassis containing discrete modules that interface over a common bus.
Page 14: Firmware Architecture
Plus INTRODUCTION TO THE UR -SERIES CHAPTER 1: GETTING STARTED Plus Figure 1: D90 block diagram Plus Figure 2: D90 hardware overview Firmware architecture Plus The D90 is organized into six major functions. • Protection. • Automation. • Metering. PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 15 Plus CHAPTER 1: GETTING STARTED INTRODUCTION TO THE UR -SERIES • Digital fault recorder (DFR). • Equipment manager. • Front panel interface (HMI). These functions operate autonomously from one another. Each function has its own configuration parameters and each generates it own output signals. All functions share the hardware and the communications facilities within the device.
Page 16: Communications Overview
Plus INTRODUCTION TO THE UR -SERIES CHAPTER 1: GETTING STARTED Figure 3: Functional architecture Communications overview Plus The EnerVista UR Setup software can communicate with the relay through three ports: the front panel USB port, the rear Ethernet port, and the rear RS485 port. Both rear ports are located in slot D.
Page 17: Enervista Software
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 18: Software Requirements
EnerVista UR Setup from the enclosed GE EnerVista CD. Insert the GE EnerVista CD into your CD-ROM drive. Click the Install Now button and follow the installation instructions to install the no- charge EnerVista software.
Page 19 CHAPTER 1: GETTING STARTED ENERVISTA SOFTWARE EnerVista Launchpad will obtain the software from the Web or CD and automatically start the installation program. Select the complete path, including the new directory name, where the EnerVista Plus Setup will be installed. Click on Next to begin the installation.
Page 20: Software Access
Using the Quick Connect Feature section for details on configuring the USB port. Plus Verify that the latest version of the EnerVista UR Setup software is installed (available from the GE EnerVista CD or online from http://gegridsolutions.com/multilin). See the Software Installation section for installation details. Plus Plus Select the “D90...
Page 21 D90 as a device at that site. Plus Verify that the latest version of the EnerVista UR Setup software is installed (available from the GE EnerVista CD or online from http://gegridsolutions.com/multilin). Plus Plus Select the “UR ”...
Page 22 ENERVISTA SOFTWARE CHAPTER 1: GETTING STARTED Setup. Click the Device Setup button to open the Device Setup window, then click the Add Site button to define a new site. Enter the desired site name in the “Site Name” field. If desired, a short description of site can also be entered along with the display order of devices defined for the site.
Page 23 USB port. Plus Verify that the latest version of the EnerVista UR Setup software is installed (available from the GE EnerVista CD or online from http://gegridsolutions.com/multilin). See the Software Installation section for installation details. Plus Plus Select the “UR...
Page 24 ENERVISTA SOFTWARE CHAPTER 1: GETTING STARTED The breaker configuration window will open and a status indicator will be displayed Plus on the lower left of the EnerVista UR Setup window. If the status indicator is red, verify that the Ethernet network cable is properly Plus connected to the Ethernet port on the back of the device and that the D90 been properly setup for communications.
Page 25: Product Description
Plus Line Distance Protection System Chapter 2: Product description Product description This section provides a basic functional overview and the technical specifications for the Plus Device overview 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 26 DEVICE OVERVIEW CHAPTER 2: PRODUCT DESCRIPTION Front panel interface Plus An intuitive and easy-to-use color graphical display is provided in the D90 front panel. The display provides easy access and visualization of device information, ranging from the large display 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.
Page 27: Protection Features
CHAPTER 2: PRODUCT DESCRIPTION DEVICE OVERVIEW Front panel USB port Plus The front panel of the D90 provides a USB 2.0 port for simple local connection. Figure 8: 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 28 DEVICE OVERVIEW CHAPTER 2: PRODUCT DESCRIPTION For additional information, refer to: Distance elements on page 183 Plus The D90 distance elements on page 627 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.
Page 29 CHAPTER 2: PRODUCT DESCRIPTION DEVICE OVERVIEW For additional information, refer to: Fault report on page 506 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. •...
Page 30 DEVICE OVERVIEW CHAPTER 2: PRODUCT DESCRIPTION Overfrequency and underfrequency protection The multiple stages of underfrequency and over frequency elements can be used to initiate load shedding or remedial actions schemes or frequency-based load restoration schemes during lack of generation in the network or due to sudden load drops. When Plus combined with the advanced automation capabilities of the D90 , flexible special...
Page 31: Automation Features
CHAPTER 2: PRODUCT DESCRIPTION DEVICE OVERVIEW Figure 10: 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 32: Equipment Manager Features
DEVICE OVERVIEW CHAPTER 2: 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 33: Digital Fault Recorder Features
CHAPTER 2: PRODUCT DESCRIPTION DEVICE OVERVIEW • Voltage phasors. • 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). •...
Page 34 DEVICE OVERVIEW CHAPTER 2: PRODUCT DESCRIPTION events. The internal clock used for time-tagging events can be synchronized with an IRIG-B signal or via the SNTP protocol over the Ethernet port. This precise time stamping allows the sequence of events to be determined throughout the system. Figure 13: Typical front panel fault report display Sequence of events recorder Plus...
Page 35: Communications Features
CHAPTER 2: PRODUCT DESCRIPTION ORDER CODES Communications features Plus The D90 incorporates powerful communications capabilities required for the demanding applications anticipated in future substations. The communications module is dedicated to processing the IEC 61850, DNP 3.0, and IEC 60870-5-104 protocols. This module provides redundant Ethernet ports each with 10/100Base-TX and 100Base-FX connectors.
Page 36: Protection Specifications
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:................
Page 37 CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS CONTACT INPUTS Input rating:............300 V DC maximum On threshold:............70% of nominal voltage setting or 20 V (whichever is greater) Off threshold: ............30% of nominal voltage setting or 15 V (whichever is greater) Bounce threshold:..........50% of nominal voltage setting or 20 V (whichever is greater) AZ threshold: ............80% of nominal voltage setting Overvoltage threshold:........130% of nominal voltage setting or 285 V maximum Maximum current:..........10 mA during turn on, 0.5 mA steady-state...
Page 38 SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION GROUND DISTANCE Characteristic:............mho (memory polarized or offset) or quad (memory polarized or non-directional), selectable individually per zone Reactance polarization:........negative-sequence or zero-sequence current Non-homogeneity angle:........–40 to 40° in steps of 1 Zones:............... 5 Directionality:............forward, reverse, or non-directional per zone Reach (secondary ohms):........0.02 to 250.00 ohms in steps of 0.01 Reach accuracy: ..........
Page 39 CHAPTER 2: PRODUCT DESCRIPTION SPECIFICATIONS Figure 15: Ground distance operating curves PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 40 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 41 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 42 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 43 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 44 SPECIFICATIONS CHAPTER 2: PRODUCT DESCRIPTION Figure 16: Phase distance operating curves PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 45 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 46 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 47: 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 48: 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 49: 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 50: 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 51: 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 52: 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 53 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 54: 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 55: 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 Inter-relay communications specifications TYPICAL DISTANCE RS422 interface: ..........1200 m (based on transmitter power; does not take into consideration the clock source provided by the user) G.703 interface: ...........100 m 850 nm laser (multimode) interface:..2.0 km (50/125 μm cable with ST connector);...
Page 56: 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 57: Installation
Plus Line Distance Protection System Chapter 3: Installation Installation Plus This section describes the physical and electrical installation of the D90 Physical installation Plus The D90 is designed as a 19-inch rack horizontal mount unit. The modular design allows the relay to be easily upgraded or repaired by a qualified service person. The faceplate is hinged to allow easy access to the removable modules.
Page 58: Rear Terminal Layout
PHYSICAL INSTALLATION CHAPTER 3: INSTALLATION Figure 17: Panel cutout dimensions Plus Figure 18: D90 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. See the following figure for an example of rear terminal assignments.
Page 59: Electrical Installation
CHAPTER 3: INSTALLATION ELECTRICAL INSTALLATION Figure 19: Rear terminal view Electrical installation Plus This section describes the electrical installation of the D90 Typical wiring Plus A typical wiring diagram for the D90 is shown below. This diagram provides an example of how to wire the device.
Page 60: Dielectric Strength
ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION Figure 20: Typical wiring diagram Dielectric strength Plus The dielectric strength of the UR -series module hardware is shown in the following table. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 61: Main Processor Module
CHAPTER 3: INSTALLATION ELECTRICAL INSTALLATION 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 (–) chassis 2000 V AC for 1 minute Power supply module...
Page 62 ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION 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 63: Communications Module
CHAPTER 3: INSTALLATION ELECTRICAL INSTALLATION IRIG-B port IRIG-B is a standard time code format that allows stamping of events to be synchronized among connected devices within one millisecond. The IRIG time code formats are serial, width-modulated codes which can be either DC level shifted or amplitude modulated (AM). Third party equipment is available for generating the IRIG-B signal;...
Page 64: Ac Modules
ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION 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. These FASTPATH: capacitors are well known to deteriorate over time if voltage is not applied periodically.
Page 65 CHAPTER 3: INSTALLATION ELECTRICAL INSTALLATION 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. It can also be connected to the CT residual circuit of a parallel line. If connected to the CT residual circuit of a parallel line, the input provides a signal for zero- NOTE: sequence mutual coupling compensation for the distance element.
Page 66: Contact Input And Output Modules
ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION Figure 25: Typical AC module wiring Contact input and output modules Every 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 may be used for the outputs of one relay.
Page 67 CHAPTER 3: INSTALLATION ELECTRICAL 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 68 ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION 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. Figure 28: Dry and wet contact input connections Wherever a tilde “~”...
Page 69 CHAPTER 3: INSTALLATION ELECTRICAL INSTALLATION Figure 29: 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 70: Inter-Relay Communication Modules
ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION 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 71 CHAPTER 3: INSTALLATION ELECTRICAL INSTALLATION Figure 30: Direct input and output dual channel connection The interconnection requirements are described in further detail in this section for each specific variation of inter-relay communications module. These modules are listed in the following table. All fiber modules use ST type connectors. Table 3: Channel communication options Module Specification...
Page 72 ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION Figure 31: Link LEDs for fiber, RS422, and G.703 modules The following 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,...
Page 73 CHAPTER 3: INSTALLATION ELECTRICAL 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, do not ground at the other end.
Page 74 ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION Figure 34: 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 35: Typical connection between two RS422 interfaces Each channel of the RS422 interface accepts a clock input for transmit timing.
Page 75 CHAPTER 3: INSTALLATION ELECTRICAL INSTALLATION Figure 36: 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 DPLL (digital phase lock loop) circuit is utilized.
Page 76 ELECTRICAL INSTALLATION CHAPTER 3: INSTALLATION 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, as shown below. Figure 38: IEEE C37.94 connection to non-compliant digital multiplexer setting is used to set the protocol and clock option for the IEEE Protocol Encoding...
Page 77: Interfaces
Plus Line Distance Protection System Chapter 4: Interfaces Interfaces Plus This section describes the methods of interfacing with the D90 Front panel overview Plus The front panel provides a convenient means to interface with the D90 . The front panel interface consists of a color LCD display (annunciator) and two sets of user-programmable Plus pushbuttons.
Page 78: Front Panel Interface Operation
FRONT PANEL OVERVIEW CHAPTER 4: INTERFACES The front panel also contains a full-speed USB port that is dedicated for communications with a PC running the EnerVista software. No settings are entered on the front panel; use the software instead. Front panel interface operation The front panel interface is a color TFT panel with pushbuttons for menu navigation and dedicated pushbuttons for control functions.
Page 79: Metering Menu
CHAPTER 4: INTERFACES FRONT PANEL OVERVIEW Figure 42: 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. There are four user- configurable metering summary screens and three fixed metering screens available. There are four user-configurable metering pages.
Page 80 FRONT PANEL OVERVIEW CHAPTER 4: INTERFACES Figure 44: Mimic page - operate example The configurable selected component display allows the user to position the selected control element and display other diagram components like metering values, breakers, disconnect switches, local/remote status, or autoreclose. The selected component display is shown below.
Page 81: Digital Fault Recorder Menu
CHAPTER 4: INTERFACES FRONT PANEL OVERVIEW Digital fault recorder menu The digital fault recorder menu provides access to various records stored within the Plus , including sequence of events, fault report, transient records, and disturbance records. The status of each function is displayed on the summary page. •...
Page 82 FRONT PANEL OVERVIEW CHAPTER 4: INTERFACES Figure 49: Example fault record The digital fault recorder menu transient record menu lists all of the records currently Plus stored in the D90 . It also indicates the status of the trigger, where: •...
Page 83: Equipment Manager Menu
CHAPTER 4: INTERFACES FRONT PANEL OVERVIEW Figure 51: Example disturbance record Equipment manager menu This menu provides access to the equipment manager battery monitor function. There are three status indicators, colored red, yellow, and green. • A green indication denotes no alarms for the device. •...
Page 84 FRONT PANEL OVERVIEW CHAPTER 4: INTERFACES Figure 53: Typical annunciator display There are three control buttons at the bottom of the display. • The Next Page button navigates through the configured alarm, self-test and product information pages. It should be noted that pages that contain no configured alarms are not displayed.
Page 85 CHAPTER 4: INTERFACES FRONT PANEL OVERVIEW • Slow flash. Alternating between the off state and the on state one time per second. In the event of an alarm, the page containing the alarm will be promoted to active page. If there are multiple pages with alarms, the page with the lowest page number is promoted.
Page 86 FRONT PANEL OVERVIEW CHAPTER 4: INTERFACES System > Installation menu. The setup program automatically updates the Configuration Plus Date after each setting change. The current D90 date and time is displayed on all annunciator pages, as is the total number of active self-tests and alarms. Communication status page The communication status page provides a summary of the currently available TCP/IP Plus...
Page 87: Enervista Software Suite
Plus Line Distance Protection System Chapter 5: EnerVista software suite EnerVista software suite The EnerVista software suite is an industry-leading set of programs that simplifies every Plus aspect of the D90 . The EnerVista suite provides tools to monitor the status of your protected asset, maintain the relay, and integrate information measured by the Plus into DCS or SCADA monitoring systems.
Page 88 Plus EXTENDED ENERVISTA UR SETUP FEATURES CHAPTER 5: ENERVISTA SOFTWARE SUITE In these situations, typically 90% or greater of the settings are identical between all devices. The templates feature allows engineers to configure and test these common settings, then lock them so they are not available to users. For example, these locked down settings can be hidden from view for field engineers, allowing them to quickly identify and concentrate on the specific settings.
Page 89 Plus CHAPTER 5: ENERVISTA SOFTWARE SUITE EXTENDED ENERVISTA UR SETUP FEATURES Editing a settings template The settings template editing feature allows the user to specify which settings are Plus available for viewing and modification in EnerVista UR Setup. By default, all settings except the FlexLogic™...
Page 90 Plus EXTENDED ENERVISTA UR SETUP FEATURES CHAPTER 5: ENERVISTA SOFTWARE SUITE Proceed through the settings tree to specify all viewable settings. Adding password protection to a template It is highly recommended that templates be saved with password protection to maximize security.
Page 91 Plus CHAPTER 5: ENERVISTA SOFTWARE SUITE EXTENDED ENERVISTA UR SETUP FEATURES Figure 60: Setting window view via the View in Template Mode command Viewing in template mode also modifies the settings tree, showing only the settings categories that contain editable settings. The effect of applying the template to a typical settings tree view is shown below.
Page 92: Securing And Locking Flexlogic™ Equations
Plus EXTENDED ENERVISTA UR SETUP FEATURES CHAPTER 5: ENERVISTA SOFTWARE SUITE The EnerVista software will remove all template information and all settings will be available. Securing and locking FlexLogic™ equations Plus The D90 allows users to secure parts or all of a FlexLogic™ equation, preventing unauthorized viewing or modification of critical FlexLogic™...
Page 93: Settings File Traceability
Plus CHAPTER 5: ENERVISTA SOFTWARE SUITE EXTENDED ENERVISTA UR SETUP FEATURES Locking FlexLogic™ equations to a serial number A settings file and associated FlexLogic™ equations can also be locked to a specific Plus serial number. Once the desired FlexLogic™ entries in a settings file have been secured, use the following procedure to lock the settings file to a specific serial number.
Page 94 Plus EXTENDED ENERVISTA UR SETUP FEATURES CHAPTER 5: ENERVISTA SOFTWARE SUITE Figure 63: Settings file traceability mechanism With respect to the above diagram, the traceability feature is used as follows. Plus The transfer date of a setting file written to a D90 is logged in the device and can Plus be viewed via EnerVista UR...
Page 95 Plus CHAPTER 5: ENERVISTA SOFTWARE SUITE EXTENDED ENERVISTA UR SETUP FEATURES Figure 65: Settings file report showing traceability data Online traceability information Plus The D90 serial number and file transfer date are available for an online device through actual values. Select the Actual Values > Product Information > Model Information menu Plus item within the EnerVista UR Setup online window as shown in the example below.
Page 96 Plus EXTENDED ENERVISTA UR SETUP FEATURES CHAPTER 5: ENERVISTA SOFTWARE SUITE PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 97: Communications Communications Overview
Plus Line Distance Protection System Chapter 6: Communications Communications Plus This section describes how to program the D90 communications settings. Communications overview Plus The D90 has one Ethernet port (port 1) on the main CPU module and two additional Ethernet ports (ports 2 and 3) on the communications module. Each port supports 100Base-FX over multi-mode fiber and 10/100Base-TX over twisted-pair, with auto- negotiation.
Page 98 COMMUNICATIONS OVERVIEW CHAPTER 6: COMMUNICATIONS Figure 67: Simple network topology without communications cards The topology shown below allows SCADA, GOOSE, configuration, and monitoring functions to share a single network. No redundancy is provided in this configuration. A Plus communications processor is required in each D90 device to facilitate SCADA and GOOSE messaging.
Page 99 CHAPTER 6: COMMUNICATIONS COMMUNICATIONS OVERVIEW Figure 69: Simple single network topology with redundancy The topology below 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 100: Network Settings
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS Figure 71: Simple dual redundant network topology The topology below illustrates a dedicated LAN for configuration and monitoring functions Plus and dual redundant LANs for SCADA and GOOSE traffic. Each D90 device will service clients on either network as required. GOOSE messages are transmitted and received on both LANs simultaneously.
Page 101 CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS The single IP redundancy configuration provides compatibility with UR-series relays and other devices with single-IP redundancy, and provides a maximum level of switchover performance. In this configuration, the port 2 IP address, subnet mask, and gateway address are used and the port 3 settings are ignored.
Page 102 NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS The IP addresses are used with the DNP, Modbus/TCP, IEC 61580, IEC 60870-5-104 and TFTP protocols. When the NSAP address or any user map setting (when used with DNP) is changed, it will NOTE: not become active until power to the relay has been cycled (off-to-on). The following settings are available for each Ethernet port, except for OSI Network Address , which are not port-specific, and the...
Page 103 CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS OSI Network Address (NSAP) Range: 20 alphanumeric characters Default: 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 00 49 00 00 00 This setting specifies the NSAP address used with the IEC 61850 protocol over the OSI (CLNP/TP4) stack.
Page 104: Tftp Protocol
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS – “>1 GATEWAY DEFINED”: The user has entered more than one default gateway. Active Port 1 IP Address, Active Port 2 IP Address, Active Port 3 IP Address Range: standard IP address range These actual values display the configured IP address for each Ethernet port. The active port IP address actual values for ports 2 and 3 are available only when the Plus contains a communications card.
Page 105: Sntp Protocol
CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS 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 These settings specify data for UDP port numbers 1 through 4. A TFTP data port value of Plus zero specifies that the D90 will automatically assign a port number.
Page 106: Http Protocol
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS Plus To use SNTP in broadcast mode, program this setting to “0.0.0.0”. The D90 then listens to SNTP messages sent to the all ones broadcast address for the subnet. The Plus waits up to eighteen minutes (1024 seconds) without receiving an SNTP broadcast message before signaling an SNTP self-test error.
Page 107: Network Filtering
CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS Figure 77: 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. This setting will Plus take affect once the D90 is rebooted.
Page 108: Ethernet Actual Values
NETWORK SETTINGS CHAPTER 6: COMMUNICATIONS Ethernet actual values Select the Actual Values > Communications > Communication menu item to open the communications actual values window. Figure 79: Ethernet actual values The following actual values are related to the Ethernet communications feature. Port 1 Ethernet Actual Mode, Port 2 Ethernet Actual Mode, Port 3 Ethernet Actual Mode Range: 10/100 BASE-TX, 10/100 BASE-FX This actual value indicates the Ethernet hardware type on each of the three ports.
Page 109: Remaining Tcp/Ip Connections Actual Values
CHAPTER 6: COMMUNICATIONS NETWORK SETTINGS Configure IP Network Status Range: OK, PORT 1 NETMASK ERROR, PORT 2 NETMASK ERROR, PORT 3 NETMASK ERROR, PORT 1 IP ADDR RSVD, PORT 2 IP ADDR RSVD, PORT 3 IP ADDR RSVD, PORT 1 IP ADDR LPBK, PORT 2 IP ADDR LPBK, PORT 3 IP ADDR LPBK, PORT 1 IP ADDR NETWK, PORT 2 IP ADDR NETWK, PORT 3 IP ADDR NETWK, PRT 1-2 SUBNET OVRLP, PRT 1-3 SUBNET OVRLP, PRT 2-3 SUBNET OVRLP, >...
Page 110: Date And Time Actual Values And Commands
MODBUS COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Date and time actual values and commands Select the Actual Values > Communications > Commands > Set Date and Time menu item to open the date and time commands window. Figure 81: Date and time actual values and commands The following date and time actual values are displayed.
Page 111: Modbus Protocol
CHAPTER 6: COMMUNICATIONS MODBUS COMMUNICATIONS to requests issued by a master device. A subset of the Modbus protocol format is supported that allows extensive monitoring, programming, and control functions using read and write register commands. Plus See the D90 Communications Guide for additional details on the Modbus protocol and the Modbus memory map.
Page 112: Dnp Communications
DNP COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 83: Modbus user map configuration settings The following Modbus user map settings are available for each of the 256 registers. Modbus Type Range: None, Settings, Actuals Default: None This setting indicates if the Modbus user map address represents a setting or an actual value.
Page 113 CHAPTER 6: COMMUNICATIONS DNP COMMUNICATIONS Figure 84: DNP protocol configuration settings The following settings are available for DNP protocol communications. DNP Channel 1 Port, DNP Channel 2 Port Range: None, COM1-RS485, Network-TCP, Network-UDP Default: None These settings specify the communications port assigned to the DNP protocol for each channel.
Page 114 DNP COMMUNICATIONS CHAPTER 6: COMMUNICATIONS DNP Client Address 1, DNP Client Address 2,..., DNP Client Address 5 Range: any standard IP address Default: 0.0.0.0 Plus These settings force the D90 to respond to a maximum of five specific DNP masters. DNP TCP/UDP Port Number Range: 1 to 65535 in steps of 1 Default: 20000...
Page 115 CHAPTER 6: COMMUNICATIONS DNP COMMUNICATIONS analog input points of that type. For example, to trigger unsolicited responses from the Plus when any current values change by 15 amps, the DNP Current Default Deadband setting should be set to “15”. These settings are the deadband default values. DNP object 34 points can be used to change deadband values from the default for each individual DNP analog input point.
Page 116: Dnp User Point List
DNP COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 85: Paired points list Points not configured as paired operate on a one-to-one basis. DNP TCP Connection Timeout Range: 10 to 300 seconds in steps of 1 Default: 120 seconds This setting specifies a time delay for the detection of dead network TCP connections. If there is no data traffic on a DNP TCP connection for greater than the time specified by Plus this setting, the connection will be aborted by the D90...
Page 117: Iec 60870-5-104 Communications
CHAPTER 6: COMMUNICATIONS IEC 60870-5-104 COMMUNICATIONS 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™...
Page 118: Iec 60870-5-104 Point Lists
IEC 60870-5-104 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS IEC Common Address of ASDU Range: 0 to 65535 in steps of 1 Default: 0 Plus This setting specifies the local address of the D90 for IEC 60870-5-104 transactions. The address is common to all data in a single ASDU (Application Service Data Unit). The combination of ASDU common address and IOA (Information Object Address) uniquely identifies each data item in a system.
Page 119: Iec 61850 Communications
CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 88: IEC 60870-5-104 user point list configuration settings The following settings are available. Binary Input Point 0, Binary Input Point 1,..., Binary Input Point 255 Range: any FlexLogic™ operand Default: Off These settings represent the IEC 60870-5-104 binary MSP points and are configured by assigning an appropriate FlexLogic™...
Page 120 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS GSSE messages can transfer changes very rapidly, making them suitable for performing interlocking and other time-critical substation functions. The IEC 61850 server supports both GOOSE and GSSE protocols in publisher and subscriber roles. In dual-IP redundant configurations, the IED transmits and listens on both ports simultaneously.
Page 121 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS 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. This name string identifies the GSSE message to the receiving device.
Page 122 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Destination MAC Range: standard MAC address format Default: 00 00 00 00 00 00 This setting specifies the destination Ethernet MAC address for the fixed GOOSE transmission. This address must be a multicast address and the least significant bit of the first byte must be set.
Page 123 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS configuration is possible, but third-party substation configuration software may be used to Plus automate the process. The EnerVista UR Setup software can produce IEC 61850 ICD files and import IEC 61850 SCD files produced by a substation configurator. Select the Settings >...
Page 124 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS VLAN ID Range: 0 to 4096 in steps of 1 Default: 0 This setting allows the selection of a specific VLAN ID for each GOOSE sending device. This value can be left at its default if the feature is not required. ETYPE APPID Range: 0 to 16383 in steps of 1 Default: 0...
Page 125 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 93: Configurable GOOSE reception configuration settings The following settings are available for each dataset for configurable GOOSE reception. 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 126 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS The IEC 61850 specification includes features that are used to cope with the loss of communication between transmitting and receiving devices. Each transmitting device will send a GSSE/GOOSE message upon a successful power-up, when the state of any included point changes, or after a specified interval (the default update time) if a change-of-state has not occurred.
Page 127 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS ETYPE APPID Range: 0 to 16383 in steps of 1 Default: 0 This setting is only used with GOOSE messages; it is not applicable to GSSE messages. This setting identifies the application identification in the GOOSE message. It should match the corresponding settings on the sending device.
Page 128 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 95: Remote inputs configuration settings The following settings are available for each of the 32 remote inputs. Name Range: up to 12 alphanumeric characters Default: Rem Ip 1 This setting allows the user to assign descriptive text to the remote input. Device Range: 1 to 32 inclusive Default: Remote Device 1...
Page 129 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of remote input events in the sequence of events recorder. Remote double-point status inputs Remote double-point status inputs are extracted from GOOSE messages originating in the Plus remote device.
Page 130 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Item Range: None, Dataset Item 1 through Dataset Item 64 Default: None This setting specifies the required bits of the GOOSE message. Default State Range: Intermediate, Off, On, Bad, Latest Default: Latest This setting selects the default value for the offline remote double-point status input. Events Range: Enabled, Disabled Default: Disabled...
Page 131 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS 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 This setting enables and disables the logging of remote output DNA bit pair events in the sequence of events recorder.
Page 132 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS IEC 61850 GOOSE analog inputs The IEC 61850 GOOSE analog inputs feature allows the transmission of analog values Plus between any two UR -series devices. Select the Settings > Communications > IEC 61850 > GSSE/GOOSE Configuration > Inputs/Outputs >...
Page 133: Iec 61850 Server Configuration
CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Table 8: Per-unit base units Element Base unit Frequency 1 Hz Phase angles 360 degrees Power factor 1.00 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.
Page 134: Logical Node Prefixes
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS MMS TCP Port Number Range: 1 to 65535 in steps of 1 Default: 102 This setting specifies the TCP port number for MMS connections. Server Scanning Range: Disabled, Enabled Default: Disabled This setting should be “Disabled” when IEC 61850 client/server functionality is not required.
Page 135 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS CILO1 LN Prefix through CILO8 LN Prefix Range: six character ASCII string Default: empty These settings specify the prefixes for the interlocking logical nodes 1 through 368. CSWI1 LN Prefix through CSWI8 LN Prefix Range: six character ASCII string Default: empty These settings specify the prefixes for the switch controller logical nodes 1 through 368.
Page 136: Mmxu Deadbands
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS RBRF1 LN Prefix, RBRF2 LN Prefix Range: six character ASCII string Default: empty These settings specify the prefixes for breaker failure logical nodes 1 and 2. RDIR1 LN Prefix, RDIR2 LN Prefix Range: six character ASCII string Default: empty These settings specify the prefixes for the directional element logical nodes 1 and 2.
Page 137 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS maximum and minimum in units of 0.00%”. Thus, it is important to know the maximum value for each MMXU measured quantity, since this represents the 100.00% value for the deadband. Select the Settings > Communications > IEC 61850 > MMXU Deadbands menu item to open the MMXU deadbands configuration window.
Page 138 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS PPV Phase AB Deadband, PPV Phase BC Deadband, PPV Phase CA Deadband Range: 0.001 to 100.000% in steps of 0.001 Default: 10.000% These settings specify the Vab, Vbc, and Vca per-phase voltage deadband values. The 100% deadband value is 275 ×...
Page 139: Ggio1 Status Configuration
CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS GGIO1 status configuration The GGIO1 logical node provides access to as many 128 digital status points and associated timestamps and quality flags. It is intended that clients use GGIO1 to access Plus digital status values from the D90 .
Page 140: Ggio4 Analog Configuration
IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS • Direct control with normal security. • SBO control with normal security. Configuration settings are available to select the control model for each point. Each protection virtual input used through GGIO2 should be enabled and the corresponding SPSCO ctlModel setting programmed to the appropriate control configuration.
Page 141 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Figure 105: 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 will exist in GGIO4. When this value is Plus changed, the D90 must be rebooted to allow the GGIO4 logical node to be re-...
Page 142: 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. Refer to IEC 61850-7-1 and IEC 61850-7-3 for additional details. This maximum value is used to determine the deadband.
Page 143: 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 144: 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 145: 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 146 IEC 61850 COMMUNICATIONS CHAPTER 6: COMMUNICATIONS Figure 109: Remote device status values The following status values are available for the IEC 61850 remote devices. The name and status values are available each of the remote devices. All Remote Devices Online Range: Yes, No This value indicates whether or not all programmed remote devices are online.
Page 147 CHAPTER 6: COMMUNICATIONS IEC 61850 COMMUNICATIONS Status Range: On, Off This value indicates the present state of the corresponding remote input. The state displayed will be that of the remote point unless the remote device has been established to be “Offline”, in which case the value shown is the programmed default state for the remote input.
Page 148: Flexstates
FLEXSTATES CHAPTER 6: COMMUNICATIONS Name Range: up to 65 alphanumeric characters This value displays the name programmed for the corresponding remote device. StNum Range: 0 to 4294967295 in steps of 1 This value is obtained from the indicated remote device and is incremented whenever a change of state of at least one DNA or UserSt bit occurs.
Page 149: Flexstate Settings
CHAPTER 6: COMMUNICATIONS FLEXSTATES sixteen (16) states may be read out in a single Modbus register. The state bits can be configured so that all of the states which are of interest to the user are available in a minimum number of Modbus registers. The state bits may be read out in the FlexStates register array beginning at Modbus address 0900h.
Page 150: Real Time Clock
REAL TIME CLOCK CHAPTER 6: COMMUNICATIONS Figure 115: FlexStates actual values The following actual values are available for each FlexState parameter. 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.
Page 151 CHAPTER 6: COMMUNICATIONS REAL TIME CLOCK Figure 116: Real time clock configuration settings The following settings are available to configure the real time clock. IRIG-B Signal Type Range: None, DC Shift, Amplitude Modulated Default: None This setting selects the type of IRIG-B signal. Select “None” to disable IRIG-B. Real Time Clock Events Range: Enabled, Disabled Default: Disabled...
Page 152: User-Programmable Self-Tests
USER-PROGRAMMABLE SELF-TESTS CHAPTER 6: COMMUNICATIONS DST Start Day Instance Range: First, Second, Third, Fourth, Last Default: First This setting specifies the which instance of the day of the week to start daylight saving time. For example, if daylight saving time begins on the second Monday in April, program this setting to “Second”.
Page 153 CHAPTER 6: COMMUNICATIONS USER-PROGRAMMABLE SELF-TESTS Figure 117: User-programmable self-test configuration settings The following settings are available to configure the user-programmable self-tests. Ethernet Port 1 Fail Function Range: Enabled, Disabled Default: Enabled When this setting is “Disabled”, the ETHERNET PORT 1 FAILURE alarm will not assert a FlexLogic™...
Page 154: Serial Port
SERIAL PORT CHAPTER 6: COMMUNICATIONS IRIG-B Fail Function Range: Enabled, Disabled Default: Enabled When this setting is “Disabled”, the IRIG-B FAILURE alarm will not assert a FlexLogic™ operand or write to the event recorder. Moreover, it will not trigger the ANY MINOR ALARM or ANY SELF-TEST messages.
Page 155: Direct Inputs And Outputs
CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Figure 118: Serial port configuration settings The following settings are available to configure the RS485 port. Baud Rate Range: 300, 600, 1200, 2400, 4800, 9600, 19200, 38400, 57600, 115200 Default: 19200 This setting specifies the baud rate (bits per second) for the RS485 port. Parity Range: None, Odd, Even Default: None...
Page 156: Direct Inputs And Outputs Configuration
DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Direct output message timing is similar to GSSE message timing. Integrity messages (with no state changes) are sent at least every 1000 ms at 64 kbps or 500 ms at 128 kbps. Messages with state changes are sent within the main pass scanning the inputs and asserting the outputs unless the communication channel bandwidth has been exceeded.
Page 157 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Ring Configuration Range: Enabled, Disabled Default: Disabled These settings are used to configure the direct input/output scheme to operate in a ring. If set to “Enabled”, all direct output messages should be received back. If not, the direct input/output ring break self-test is triggered.
Page 158: Direct Input And Output Applications
DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Message Alarm Function Range: Enabled, Disabled Default: Disabled Plus The D90 checks integrity of the direct input/output communication ring by counting unreturned messages. In the ring configuration, all messages originating at a given device should return within a pre-defined period of time.
Page 159 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS The following settings should be applied to implement this application. For both IEDs, set the inter-relay baud rate for channel 1 to 128 kbps in the Settings > Communications > Inter-Relay menu. Plus For UR -series IED 1: Figure 121: Inter-relay communications settings for IED 1...
Page 160 DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Figure 124: 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); that is, from device 1 to device 2, and from device 2 to device 1. Different communications cards can be selected by the user for this back-to-back connection (for example: fiber, G.703, or RS422).
Page 161 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Figure 126: Interlocking busbar protection scheme via direct inputs and outputs The following settings should be applied to implement this application. For IED 1, set the inter-relay application for both channels as follows in the Settings > Communications > Inter-Relay menu.
Page 162 DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Figure 129: Direct input and output settings for IED 1 Plus For UR -series IED 2: Figure 130: Direct input and output settings for IED 2 Plus For UR -series IED 3: Figure 131: Direct input and output settings for IED 3 Plus For UR -series IED 4:...
Page 163 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Figure 132: 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. Dual-ring configuration effectively reduces the maximum communications distance by a factor of two.
Page 164 DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Figure 133: Three-terminal line application A permissive pilot-aided or blocking scheme can be accomplished using a dual-ring configuration as shown below. Figure 134: Dual-channel closed loop (dual-ring) configuration The following settings should be applied to implement this application. For all IEDs, set the inter-relay application for both channels as follows in the Settings >...
Page 165 CHAPTER 6: COMMUNICATIONS DIRECT INPUTS AND OUTPUTS Figure 137: Direct input and output settings for IED 1 Plus For UR -series IED 2: Figure 138: Direct input and output settings for IED 2 Plus For UR -series IED 3: Figure 139: Direct input and output settings for IED 3 In this configuration the following delivery times are expected (at 128 kbps) if both the rings are healthy: PLUS...
Page 166: Direct Inputs And Outputs Statistics
DIRECT INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Table 11: Expected delivery times for healthy rings Path Delivery time IED 1 to IED 2 0.2 of a power system cycle IED 1 to IED 3 0.2 of a power system cycle IED 2 to IED 3 0.2 of a power system cycle This configuration can be applied to both permissive and blocking schemes.
Page 167: Teleprotection Inputs And Outputs
CHAPTER 6: COMMUNICATIONS TELEPROTECTION INPUTS AND OUTPUTS Figure 141: Inter-relay communications commands The following command is available for the direct inputs and outputs. Clear Direct I/O Counters This command clears the statistic counters for the direct input/output CRC fail count and the unreturned message count.
Page 168: Teleprotection Channel Tests
TELEPROTECTION INPUTS AND OUTPUTS CHAPTER 6: COMMUNICATIONS Local Relay ID Range: 0 to 255 in steps of 1 Default: 0 In installations that use multiplexers or modems, it is desirable to ensure that the data used by the devices protecting a given line is from the correct device. The teleprotection Plus function performs this check by reading the message ID sent by transmitting UR series devices and comparing it to the programmed terminal IDs in the receiving device.
Page 169: Inter-Relay Communications
CHAPTER 6: COMMUNICATIONS INTER-RELAY COMMUNICATIONS Figure 144: Inter-relay communications commands The following teleprotection command is available. Clear Teleprotection Counters This command clears the number of teleprotection lost packets count. Inter-relay communications The inter-relay communications settings are used to configure inter-relay communications for direct inputs and outputs and teleprotection inputs and outputs.
Page 170: Inter-Relay Communication Actual Values
INTER-RELAY COMMUNICATIONS CHAPTER 6: COMMUNICATIONS channels when the IEDs are configured in a redundant ring. This provides a greater level of security if one of the rings become disconnected. This mode should be used when interfacing with UR-series devices. Inter-Relay Baud Rate Range: 64 kbps, 128 kbps Default: 64 kbps This setting selects the baud rate for each inter-relay communications channel.
Page 171 CHAPTER 6: COMMUNICATIONS INTER-RELAY COMMUNICATIONS Figure 146: Inter-relay communication actual values The following inter-relay communication actual values are available for each channel. Transceiver Temperature Range: –99.99 to 300.00 °C This value indicates the fiber transceiver temperature. Transceiver Temperature Trouble Range: On, Off This value indicates whether the fiber transceiver temperature has exceeded the manufacturer’s limit.
Page 172: Inter-Relay Communication Commands
INTER-RELAY COMMUNICATIONS CHAPTER 6: COMMUNICATIONS 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 manufacturer’s limit.
Page 173: Communication Logic Operands
CHAPTER 6: COMMUNICATIONS COMMUNICATION LOGIC OPERANDS Communication logic operands Plus The following communication logic operands are available for the D90 . They are listed alphabetically by operand syntax The definitions listed below reflect the default operand names. If desired, these operands can be assigned user-defined names through the Settings >...
Page 174: Customizing The Communication Logic Operands
COMMUNICATION FLEXANALOG™ PARAMETERS CHAPTER 6: COMMUNICATIONS Customizing the communication logic operands Select the Settings > Configure FlexOperands menu item to open the user-configurable operands window. Figure 148: 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 selecting the Comms tree item.
Page 175 CHAPTER 6: COMMUNICATIONS COMMUNICATION FLEXANALOG™ PARAMETERS GOOSE Analog In 2........The value above is available for GOOSE analog input 2 to 128 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 176 COMMUNICATION FLEXANALOG™ PARAMETERS CHAPTER 6: COMMUNICATIONS PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 177: Protection Protection Overview
Plus Line Distance Protection System Chapter 7: Protection Protection Plus This section describes 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 178 PROTECTION OVERVIEW CHAPTER 7: PROTECTION above the setting and 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 parameter actual values as the input. Protection elements are arranged into two classes, grouped and control.
Page 179: Power System
CHAPTER 7: PROTECTION POWER SYSTEM supervise the comparator. The BLOCK input is used as one of the inputs to RUN control. • setting: This setting is used to control whether the pickup, dropout or operate Events states are recorded by the event recorder. When set to “Disabled”, element pickup, dropout or operate are not recorded as events.
Page 180: 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 181 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 182 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 183 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 typically used to derive secondary voltage values from the per-unit settings used in protection elements.
Page 184 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 below. For delta connections, the power cut-off is calculated as follows. Eq.
Page 185: Power System Frequency
CHAPTER 7: PROTECTION POWER SYSTEM Power system frequency Select the Settings > Protection > Power System > Frequency menu item to open the power system frequency configuration window. Figure 154: System frequency configuration settings The following settings are available. Nominal Frequency Range: 50 Hz, 60 Hz Default: 60 Hz The power system...
Page 186: About Ac Sources
Frequency Tracking Range: Disabled, Enabled Default: Enabled This setting should only be programmed to “Disabled” in very unusual circumstances; consult GE Grid Solutions for special variable-frequency applications. About AC sources Plus The D90 may 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 187 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 could flow. Auxiliary CTs are required to perform ratio matching if Plus the ratios of the primary CTs to be summed are not identical.
Page 188 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 will be 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 189: Grouped Protection Elements
CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 157: Disturbance detector logic scheme Example use of sources Plus Consider a D90 connected as shown below. This configuration could be used on a transmission line connected into a breaker-and-a-half system. The following 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 190 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 autoreclosure is employed.
Page 191 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 192 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 193: Distance Elements
CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 160: Line pickup scheme logic Distance elements Four common settings are available for distance protection. Select the Settings > Protection > Elements > Group 1 > Distance > Common menu item to open the distance configuration window.
Page 194 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 161: 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 195 The CVT filter function should be disabled if the T1, T2, and Tx parameters are not known (the default values should not be used). Contact GE Grid Solutions for assistance in determining these settings.
Page 196 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 162: 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 197 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 163: 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 198 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 164: Directional mho phase distance characteristic Figure 165: Non-directional mho phase distance characteristic PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 199 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 166: Directional quadrilateral ground distance characteristic Figure 167: Non-directional quadrilateral ground distance characteristic Sample shapes for the mho and quadrilateral distance characteristics are shown below. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 200 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 168: Mho distance characteristic sample shapes PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 201 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 169: 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 202 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 203 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 204 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. The angular position of the blinder is adjustable with the use of the setting.
Page 205 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 will disable 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 206 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 172: Phase distance zone 2 operation scheme logic The phase distance scheme logic for zone 1 is shown below. The logic is analogous for zones 2 through 5. Figure 173: Phase distance scheme logic PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 207 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 208 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 174: 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 209 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 175: Directional mho ground distance characteristic Figure 176: Non-directional mho ground distance characteristic PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 210 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 177: Directional quadrilateral ground distance characteristic Figure 178: Non-directional quadrilateral ground distance characteristic PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 211 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 212 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 213 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 214 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION This setting should be at least three times the setting specified in Current Cutoff Level the 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 215 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 180: Ground distance zone 2 operation scheme logic The ground distance scheme logic for zone 1 is shown below. Figure 181: Ground distance zone 1 scheme logic The ground distance scheme logic for zone 2 is shown below. The logic is analogous for zones 3 through 5.
Page 216 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 182: Ground distance zone 2 scheme 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 a maloperation of the ground element in a sound phase if the zone reach setting is increased to cover high resistance faults.
Page 217 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 183: Ground directional supervision scheme logic Power swing detect settings 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 218 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION first step is similar to the power swing blocking sequence. After the timer specified by the setting times out, latch 1 is set as long as the impedance stays within the Pickup Delay 1 outer characteristic.
Page 219 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 185: Effect of blinders on the mho operating characteristic Figure 186: Power swing detect quadrilateral operating characteristic The FlexLogic™ output operands for the power swing detect element are described below. Power swing detection operands POWER SWING 50DD.......Asserted when the power swing detection element detects a disturbance other than a power swing.
Page 220 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 221 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 222 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 223 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 value would be close to the average of the outer and inner limit angles.
Page 224 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 should be set to detect the fastest expected power swing and produce out-of-step tripping in a secure manner. The timers should be set in consideration to the power swing detect characteristics, mode of power swing detect operation and mode of out-of-step tripping.
Page 225 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 226 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 189: Power swing detect scheme logic, sheet 2 of 3 Figure 190: Power swing detect scheme logic, sheet 3 of 3 Load encroachment settings The load encroachment element responds to the positive-sequence voltage and current and applies the characteristic shown below.
Page 227 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 191: 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 228 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 193: Load encroachment configuration settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled This setting enables and disabled 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 229 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 230 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION current supervision above the maximum load current and use the fuse failure function as well. The current supervision prevents maloperation immediately after the fuse fail condition giving some time for the fuse failure element to take over and block the distance elements permanently.
Page 231 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS the load impedance may enter into the relay characteristic for a time longer than the chosen time delay, which could occur transiently during a system power swing. For this reason the power swing blocking function should be used. Phase distance zone 4 guidelines for the stepped distance scheme As a further contribution to remote backup, the reach of this element must be set to account for any infeed at the remote bus.
Page 232 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 195: Understanding system homogeneity Given the equivalent systems shown in the figure above, the angular difference between Plus the zero-sequence or negative-sequence current at the D90 and the fault current can be calculated as follows. Eq.
Page 233 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS multiple points. A fault beyond 100% of the protected line may cause overreach unless the reach is reduced significantly, sometimes as low as 65% of the line length. If the line being protected does not have a significant interaction with an adjacent circuit, then the typical 80% setting may be used.
Page 234 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION A line compensating capacitor is a bank of three physical capacitors and their overvoltage protecting devices (air gaps, MOVs, or both). If none of the MOV or gaps conducts any significant current, the positive-sequence, negative-sequence, and zero-sequence reactance of the three-phase bank equal the reactance of the actual (phase) capacitors.
Page 235 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Ground directional overcurrent guidelines for protecting series compensated lines The ground directional overcurrent function (negative-sequence overcurrent or neutral overcurrent) uses an offset impedance to guarantee correct fault direction discrimination. The following setting rules apply. If the net impedance between the potential source and the local equivalent system is inductive, then there is no need for an offset.
Page 236: Current Elements
Overview of 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™...
Page 237 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS other relays, such as most static relays, which set the energy capacity directly to zero when the current falls below the reset threshold. The timed method can be used where the relay must coordinate with electromechanical relays. IEEE curves The IEEE time overcurrent curve shapes conform to industry standards and the IEEE C37.112-1996 curve classifications for extremely, very, and moderately inverse curves.
Page 238 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Multiplier Current (I / I pickup (TDM) 10.0 10.0 161.790 70.277 29.423 17.983 13.081 10.513 8.995 8.023 7.361 6.891 IEEE moderately inverse 3.220 1.902 1.216 0.973 0.844 0.763 0.706 0.663 0.630 0.603 6.439 3.803 2.432 1.946 1.688...
Page 239 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Multiplier Current (I / I pickup (TDM) 10.0 0.80 13.755 8.023 5.042 3.984 3.424 3.070 2.822 2.637 2.493 2.376 1.00 17.194 10.029 6.302 4.980 4.280 3.837 3.528 3.297 3.116 2.971 IEC curve B 0.05 1.350 0.675 0.338...
Page 240 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 241 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS t curves The I t curves are derived as follows. Eq. 16 Eq. 17 The terms in the above equations are defined as follows. • represents the operate time in seconds. operate • TDM represents the multiplier setting. •...
Page 242 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Definite time curve The definite time curve shape operates as soon as the pickup level is exceeded for a specified period of time. The base definite time curve delay is in seconds. The curve multiplier of 0.00 to 600.00 makes this delay adjustable from instantaneous to 600.00 seconds in steps of 10 ms.
Page 243 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Select the Settings > Protection > Elements > Group 1 > Current > Phase TOC menu item to open the phase time overcurrent configuration window. Figure 198: Phase time overcurrent configuration settings The following settings are available for each phase time overcurrent element. Function Range: Enabled, Disabled Default: Disabled...
Page 244 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 245 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 199: Phase time overcurrent 1 scheme logic Phase instantaneous overcurrent The phase instantaneous overcurrent element may be used as an instantaneous element with no intentional delay or as a definite time element. The input current is the fundamental phasor magnitude.
Page 246 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 phase instantaneous overcurrent protection element. Pickup Range: 0.000 to 30.000 pu in steps of 0.001 Default: 1.000 pu This setting specifies the phase instantaneous overcurrent pickup level in per-unit values.
Page 247 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 201: 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 248 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION The phase directional overcurrent 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 249 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 203: 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 250 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 251 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Select the Settings > Protection > Elements > Group 1 > Current > Neutral TOC menu item to open the neutral time overcurrent configuration window. Figure 205: Neutral time overcurrent configuration settings The following settings are available for each neutral time overcurrent element. Function Range: Enabled, Disabled Default: Disabled...
Page 252 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 253 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS 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 254 GROUPED PROTECTION ELEMENTS 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 neutral instantaneous overcurrent element. Events Range: Enabled, Disabled Plus Plus Default: varies with UR -series model;...
Page 255 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS The positive-sequence restraint is removed for low currents. If the positive-sequence current is less than 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 256 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 209: 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 will be delayed by 1.5 of a power system cycle.
Page 257 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 210: 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 258 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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, it should be ensured that a reversal of the ground current does not occur for a high-side fault.
Page 259 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS 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 260 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 211: Neutral directional overcurrent 1 scheme logic Ground time overcurrent The ground time overcurrent element can provide a desired 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 261 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 212: 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 262 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 263 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 214: 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 264 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Events Range: Enabled, Disabled Plus Plus Default: varies with UR -series model; refer to the EnerVista UR Setup software This setting enables and disables the logging of ground instantaneous overcurrent events in the sequence of events recorder. The logic for the ground instantaneous overcurrent 1 element is shown below.
Page 265 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 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 266 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 217: Negative-sequence time overcurrent scheme logic Negative-sequence instantaneous overcurrent The negative-sequence instantaneous overcurrent element may 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 267 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS 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 268 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 269 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS must be greater than the setting value specified in the Protection > Current Cutoff Level Power System > AC Inputs – Current menu. The following figure explains the usage of the voltage polarized directional unit of the element. Figure 220: Negative-sequence directional characteristics The forward-looking function is designed to be more secure as compared to the reverse- looking function, and therefore, should be used for the tripping direction.
Page 270 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 221: 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 271 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS 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 to zero to remove the restraint. Set to a higher value if large system unbalances or poor CT performance are expected.
Page 272: Voltage Elements
GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 222: 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 which may cause dangerous overheating in the motor.
Page 273 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 223: 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 may be used to give a desired time delay operating characteristic versus the applied fundamental voltage (phase-to-ground or phase-to- phase for wye VT connections, or phase-to-phase for delta VT connections) or as a definite time element.
Page 274 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Mode Range: Phase to Ground, Phase to Phase Default: Phase to Ground This setting selects the operating mode. Select phase-to-ground or phase-to-phase for wye VT connections, or phase-to-phase for delta VT connections. Pickup Range: 0.000 to 1.100 pu in steps of 0.001 Default: 1.000 pu This setting specifies the phase undervoltage pickup level in per-unit values.
Page 275 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS PHASE UV1 OP B.........Asserted when phase B of the phase undervoltage 1 element operates. PHASE UV1 OP C.........Asserted when phase C of the phase undervoltage 1 element operates. PHASE UV1 PKP...........Asserted when at least one phase of the phase undervoltage 1 element picks up.
Page 276 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 226: 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 277 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 227: Phase overvoltage scheme 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 278 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 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 279 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Negative-sequence overvoltage The negative-sequence overvoltage element may 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 item to open the negative-sequence overvoltage configuration window.
Page 280 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 logic for the negative-sequence overvoltage 1 element is shown below. The logic is similar for all negative-sequence overvoltage elements.
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 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 282 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 283: Breaker Failure
CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of auxiliary overvoltage events in the sequence of events recorder. The logic for the auxiliary overvoltage element is shown below. The logic is identical for all auxiliary overvoltage elements.
Page 284 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 237: 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 285 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS 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 286 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 238: 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 287 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Use Seal-In Range: Yes, No Default: Yes If set to “Yes”, the breaker failure element will only be sealed-in if current flowing through the breaker is above the supervision pickup level. Three Pole Initiate Range: any FlexLogic™...
Page 288 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Plus In the UR -series devices, which use a Fourier transform, the calculated current magnitude will ramp-down to zero one power frequency cycle after the current is interrupted, and this lag should be included in the overall margin duration, as it occurs after current interruption.
Page 289 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS 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 should detect the lowest expected fault current on the protected breaker, before a breaker opening resistor is inserted.
Page 290 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 may even be adjusted to have the shortest possible operating time.
Page 291 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 239: Breaker failure single-pole logic, sheet 1 of 3 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 292 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 240: Breaker failure single-pole logic, sheet 2 of 3 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 293 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 241: Breaker failure single-pole logic, sheet 3 of 3 Figure 242: Breaker failure three-pole logic, sheet 1 of 3 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 294: Wattmetric Zero-Sequence Directional Ground Fault
GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION Figure 243: Breaker failure three-pole logic, sheet 2 of 3 Figure 244: 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 295 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 245: 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 296 GROUPED PROTECTION ELEMENTS CHAPTER 7: PROTECTION 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 297 CHAPTER 7: PROTECTION GROUPED PROTECTION ELEMENTS Figure 246: 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 298: Control Elements
CONTROL ELEMENTS CHAPTER 7: PROTECTION In this equation, m is a multiplier defined by the multiplier setting, S represents the pickup setting, and S represents 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.
Page 299: Pilot-Aided Schemes
CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 300 CONTROL ELEMENTS CHAPTER 7: PROTECTION The following settings are available for the direct under-reaching transfer trip (DUTT) scheme. 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™...
Page 301 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 249: DUTT scheme logic Permissive under-reaching transfer trip The permissive under-reaching transfer trip (PUTT) scheme uses an under-reaching zone 1 distance element to key transfer trip signal to the remote terminals where they are supervised by an over-reaching zone 2 distance element.
Page 302 CONTROL ELEMENTS CHAPTER 7: PROTECTION The following settings are available for the permissive under-reaching transfer trip (PUTT) scheme. 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 303 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 251: PUTT scheme logic Permissive over-reaching transfer trip The permissive over-reaching transfer trip (POTT) scheme is intended for two-terminal line applications only. This scheme uses an over-reaching zone 2 distance element to essentially 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 304 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 252: POTT scheme configuration settings The following settings are available for the permissive over-reaching transfer trip (POTT) scheme. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the permissive over-reaching transfer trip (POTT) scheme.
Page 305 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 306 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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™...
Page 307 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 permissive over-reaching transfer trip (POTT) scheme logic is shown below. Figure 253: POTT scheme logic Hybrid permissive over-reaching transfer trip The hybrid permissive over-reaching transfer trip (hybrid POTT) scheme generally uses an...
Page 308 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 should be enabled and configured to detect line-end-open or weak-infeed and undervoltage conditions.
Page 309 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 (refer to the logic diagram below). If set to “Custom”, the echo signal is sent if the condition selected by the setting is Echo Condition...
Page 310 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 311 CHAPTER 7: PROTECTION CONTROL ELEMENTS these elements have separate forward and reverse output operands. The reverse indication should be used (that is, NEG SEQ DIR OC1 REV NEUTRAL DIR OC1 REV). The selected protection element (or elements in combination) should be coordinated with the selection of the setting.
Page 312 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 255: Hybrid POTT scheme 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 313 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 314 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 should 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 315 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 316 CONTROL ELEMENTS CHAPTER 7: PROTECTION be de-asserted by the scheme based on the phase selection providing the peer device with more information on the fault type. Otherwise, the peer device issues a three-pole trip upon receiving the [0, 0, 0, 0] bit pattern. RX1, RX2, RX3, RX4 Range: any FlexLogic™...
Page 317 CHAPTER 7: PROTECTION CONTROL ELEMENTS Directional comparison unblocking The directional comparison unblocking scheme is available for single-pole tripping applications and can be used with one, two, or four bit communications channels. Choices of communications channel include remote inputs, remote outputs, and telecommunications interfaces.
Page 318 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 258: Directional comparison unblocking scheme configuration settings The following settings are available for the directional comparison unblocking scheme. Function Range: Enabled, Disabled Default: Disabled This setting enables and disabled the directional comparison unblocking scheme. Block Range: any FlexLogic™...
Page 319 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 320 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 would be unnecessarily delayed.
Page 321 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 setting values are from 4 to 32 ms. For most cases, a value of 8 ms may 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 322 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 are typically used. These settings must be used in conjunction with the loss-of-guard signals, otherwise the scheme will not unblock and thus fail to operate.
Page 323 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 259: Directional comparison unblocking scheme logic, sheet 1 of 2 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 324 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 260: Directional comparison unblocking scheme logic, sheet 2 of 2 Pilot-aided scheme application guidelines This section provides general application guidelines for implementing pilot-aided schemes Plus 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 325 CHAPTER 7: PROTECTION CONTROL ELEMENTS For proper operation of the scheme the zone 1 and 2 phase and ground distance elements must be enabled, configured, and set per the standard rules of distance relaying. The scheme generates an output operand (PUTT TX) that is used to transmit the signal to the remote end.
Page 326 CONTROL ELEMENTS CHAPTER 7: PROTECTION Unlike the distance protection elements, the ground directional overcurrent functions do not have a well-defined reach. As such, he current reversal logic is incorporated for the extra signal supplementing zone 2 in the scheme. The transient blocking approach for this POTT scheme is to recognize that a permissive signal has been received and then allow the time specified by the Transient Block Pickup Delay...
Page 327 CHAPTER 7: PROTECTION CONTROL ELEMENTS The output operand from the hybrid POTT scheme (HYBRID POTT OP) must be configured to Plus interface with other D90 functions (output contacts in particular) to make the scheme fully operational. The output operand should typically be programmed to initiate a trip, breaker failure, and autoreclose, as well as drive a user-programmable LED as per user requirements.
Page 328 CONTROL ELEMENTS CHAPTER 7: PROTECTION Directional comparison unblocking (DCUB) application guidelines The directional comparison unblocking (DCUB) scheme is used with a frequency shift keying (FSK) PLC that produces a loss-of-guard output during an actual loss-of-guard signal condition and during reception of the permissive keyed frequency when the received carrier signal changed from guard to permissive frequency.
Page 329 CHAPTER 7: PROTECTION CONTROL ELEMENTS • The directional comparison unblocking scheme is not locked out. The trip table is run if all of these conditions are met. This operates the scheme and asserts FlexLogic™ operand. The trip table, with the aid of the local phase selector and DCUB OP received RX signals, will determine what tripping operands will be operated.
Page 330: Setting Group Control
CONTROL ELEMENTS CHAPTER 7: PROTECTION • A fault is not seen in the forward zone 2 distance elements or ground directional forward function (if configured) for at least 100 ms. • The reverse zone 4 distance elements or ground directional reverse function (if configured) did not pickup to set the transient blocking.
Page 331 CHAPTER 7: PROTECTION CONTROL ELEMENTS Group 2 Activate On, Group 3 Activate On, Group 4 Activate On, Group 5 Activate On, Group 6 Activate On Range: any FlexLogic™ operand or shared operand Default: OFF Each of these settings selects an operand which, when set, will activate the corresponding setting group for use by any grouped element.
Page 332: Trip Output
CONTROL ELEMENTS CHAPTER 7: PROTECTION Trip output The trip output element is primarily used to collect trip requests from protection elements and other inputs to generate output operands to initiate trip operations. Three-pole trips will only initiate reclosure if programmed to do so, whereas single-pole trips will always automatically initiate reclosure.
Page 333 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 263: 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 334 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 with this setting remains picked-up. The open pole detector provides blocking inputs to distance elements;...
Page 335 CHAPTER 7: PROTECTION CONTROL ELEMENTS single-pole tripping applications when evolving faults are of importance and slightly delayed operation on evolving faults could 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 This setting should be used in conjunction with the Reverse Fault...
Page 336 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 264: Trip output scheme logic, sheet 1 of 2 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 337: Flexmatrix
CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 265: Trip output scheme 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 338 CONTROL ELEMENTS CHAPTER 7: PROTECTION FlexMatrix inputs Select the Settings > Protection > Control > FlexMatrix > FlexMatrix Inputs menu item to access the FlexMatrix input settings. Figure 266: 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™...
Page 339 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 267: 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 340: Vt Fuse Failure
CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 341 CHAPTER 7: PROTECTION CONTROL ELEMENTS The VT fuse failure detector can be used to raise an alarm or block elements that may operate incorrectly for a full or partial loss of AC potential caused by one or more blown fuses. Some elements that might be blocked (via the Block setting) include voltage restrained overcurrent and directional current.
Page 342: Open Pole Detector
CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 270: VT fuse failure scheme logic Open pole detector The open pole detector is intended to identify an open pole of the line circuit breaker. The scheme monitors the breakers auxiliary contacts, current in the circuit, and voltage (optional) on the line.
Page 343 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 271: Open pole detector configuration settings The following settings are available for the open pole detector feature. Function Range: Enabled, Disabled Default: Disabled This setting enables and disabled the open pole detector feature. Block Range: any FlexLogic™...
Page 344 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 345: Autoreclose
CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 273: Open pole detector scheme logic, sheet 2 of 2 Autoreclose The autoreclose scheme is intended for use on transmission lines with circuit breakers operated in both the single-pole and three-pole modes, in one or two breaker arrangements.
Page 346 CONTROL ELEMENTS CHAPTER 7: PROTECTION Autoreclose programs The autorecloser provides four programs that can cause from one to four reclose attempts (shots). After the first shot, all subsequent reclosings will always be 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 will go to lockout upon another initiate signal.
Page 347 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 274: Autoreclose scheme enable logic Figure 275: Autoreclose scheme initiate logic A reclose initiate signal will send the scheme into the reclose-in-progress (RIP) state and assert 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 348 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 276: Autoreclose scheme reclose-in-progress logic After entering the reclose-in-progress state, a close command will be issued after the dead time delay. The dead time for the initial reclose operation will be determined by either the 1-P Dead Time 3-P Dead Time 1 , or...
Page 349 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 277: Autoreclose scheme breaker close logic Figure 278: Autoreclose scheme close breaker 1 or 2 logic Figure 279: Autoreclose scheme termination Multi-shot operation setting defines the number of reclose attempts. After each Maximum Number of Shots reclose the shot counter is incremented.
Page 350 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 280: Autoreclose scheme shot counter logic Autoreclose pause input The autoreclose pause input offers the possibility of freezing the autoreclose cycle until the pause signal disappears. This may 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 351 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 282: Autoreclose scheme 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 if the Transfer 1 to setting is “Yes”.
Page 352 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 283: Autoreclose scheme failure-to-close logic Figure 284: Typical autoreclose sequence PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 353 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 is also provided that inhibits a breaker reclose if that breaker was open in advance of a reclose initiate input to the recloser.
Page 354 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 355 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 287: Autoreclose scheme lockout logic PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 356 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 357 CHAPTER 7: PROTECTION CONTROL ELEMENTS • Breaker 2 issues a manual close and 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 290: Autoreclose scheme manual close logic Terminal closed The close logic uses the status of each breaker to determine whether the terminal is closed.
Page 358 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 292: Autoreclose scheme 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 359 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 293: 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 360 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 294: Terminal one-pole open logic Autoreclose settings Select the Settings > Protection > Control > Autoreclose menu item to access the autoreclose settings. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 361 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 295: Autoreclose settings window The following settings are available for the autoreclose element. 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 362 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 363 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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™...
Page 364 CONTROL ELEMENTS CHAPTER 7: PROTECTION Extend Dead Time 1 Range: any FlexLogic™ operand or shared operand Default: Off This setting selects an operand that will 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 365 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 366 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 will be transferred to breaker 1 which will continue the reclosing cycle until successful (the scheme will reset) or unsuccessful (the scheme will go to lockout).
Page 367 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 296: Final autoreclose signal flow logic Front panel status and control If the autoreclose function is enabled, an indication will appear on the screen. This indication indicates the operational status of the autoreclose function as defined below. Table 20: Autoreclose front panel indications Indication FlexLogic™...
Page 368: Underfrequency
CONTROL ELEMENTS CHAPTER 7: PROTECTION Indication FlexLogic™ operand Autoreclose Locked Out AR LO 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 will be grey and not operable.
Page 369 CHAPTER 7: PROTECTION CONTROL ELEMENTS Select the Settings > Protection > Control > Underfrequency menu item to open the underfrequency settings window. Figure 299: 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.
Page 370: Overfrequency
CONTROL ELEMENTS CHAPTER 7: PROTECTION Reset Delay Range: 0.000 to 65.535 seconds in steps of 0.001 Default: 2.000 seconds This setting specifies a time delay on dropout for the duration between the operate output state and the return to logic 0 after the input transits outside the defined pickup range.
Page 371 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 301: 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 372: Breaker Configuration
CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 302: Overfrequency scheme 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 373 CHAPTER 7: PROTECTION CONTROL ELEMENTS Long Name Range: 20 alphanumeric characters Default: Breaker 1 This setting is used to identify 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 374 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 375 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 376 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 304: Breaker configuration logic, sheet 1 of 4 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 377 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 305: Breaker configuration logic, sheet 2 of 4 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 378 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 306: Breaker configuration logic, sheet 3 of 4 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 379: Breaker Flashover
CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 307: 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.
Page 380 CONTROL ELEMENTS CHAPTER 7: PROTECTION Breaker flashover settings Select the Settings > Protection > Control > Breaker Flashover menu item to open the breaker flashover configuration window. Figure 308: Breaker flashover configuration settings The following settings are available for each breaker flashover element. Function Range: Enabled, Disabled Default: Disabled...
Page 381 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 382 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 309: Breaker flashover scheme logic, sheet 1 of 2 Figure 310: Breaker flashover scheme logic, sheet 2 of 2 Three VT breaker flashover application When only one set of VTs is available across the breaker, the setting should be Side 2 “None”.
Page 383 CHAPTER 7: PROTECTION CONTROL ELEMENTS input 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 will not be considered as a condition for open breaker in this part of the logic. Voltages must be present prior to flashover conditions.
Page 384: Digital Counters
CONTROL ELEMENTS CHAPTER 7: PROTECTION Consider the configuration below. Figure 312: 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 385 CHAPTER 7: PROTECTION CONTROL ELEMENTS 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 may be assigned to a digital counter for diagnostic, setting, and event recording purposes.
Page 386 CONTROL ELEMENTS CHAPTER 7: PROTECTION 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 will be set to the preset value when the counter is enabled and the operand assigned to the setting is asserted (logic 1).
Page 387: Flexcurves
CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 314: Digital counter scheme 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 388 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 315: 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 389 CHAPTER 7: PROTECTION CONTROL ELEMENTS Figure 316: 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 390 CONTROL ELEMENTS CHAPTER 7: PROTECTION Figure 317: Recloser curve initialization The multiplier and adder settings only affect the curve portion of the characteristic and not NOTE: the MRT and HCT settings. The HCT settings override the MRT settings for multiples of pickup greater than the HCT ratio.
Page 391: Protection Inputs And Outputs
CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 319: 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 392 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 320: Protection virtual inputs configuration settings The following settings are available for each protection virtual input. The default values shown are for virtual input 1. Function Range: Enabled, Disabled Default: Disabled If this setting is “Disabled”, the virtual input will be forced to off (logic 0) regardless of any attempt to alter the input.
Page 393: Protection Virtual Outputs
CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 321: Protection virtual input logic Protection virtual input actual values Select the Actual Values > Protection > Protection Inputs/Outputs > Virtual Inputs menu item to open the protection virtual input actual values window. Figure 322: Protection virtual input actual values The following actual values are available for all enabled protection virtual inputs.
Page 394 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 323: Protection virtual output settings The following settings are available for each protection virtual output. If not assigned, the virtual output will be forced to off (logic 0). Range: up to 12 alphanumeric characters Default: Virt Op 1 This setting specifies an identifier that may be assigned to each protection virtual output.
Page 395: Contact Input Configuration
CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Name Range: up to 12 alphanumeric characters This value displays the programmed for the corresponding protection virtual output. Status Range: On, Off This value indicates the logic state of the protection virtual output. Contact input configuration Plus The D90...
Page 396 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION The FlexLogic™ operand response time to the contact input change is equal to the debounce time setting plus a maximum of one protection pass (depending on system frequency if frequency tracking is enabled). If the change of state occurs just after a protection pass, the recognition is delayed until the subsequent protection pass (that is, by the entire duration of the protection pass).
Page 397 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 326: Contact input and output assignments All available contact inputs and output can be reassigned using the >> and << buttons. Contact input settings When the input detects a voltage decrease, the input circuitry will draw 10 mA of current. If the voltage decrease is due to a state change then the voltage will quickly decrease, speeding up the recognition of the reset of the field contact.
Page 398 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Range: up to 12 alphanumeric characters Default: Cont Ip 1 An alphanumeric ID may be assigned to a contact input for diagnostic, setting, and event recording purposes. The “CONTACT IP 1” text in event records and FlexLogic™ operands will be replaced by the text programmed in this setting.
Page 399 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 328: Chatter detection example Select the Settings > Protection > Protection Inputs/Outputs > Contact Inputs > Chatter Detection menu item to access the contact input chatter detection settings. Figure 329: Contact input chatter detection configuration The following settings are applied to all available protection and automation contact inputs.
Page 400: Contact Outputs
PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 330: 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 401: Direct Inputs
CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS 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 will seal-in the contact output when asserted. Voltage Threshold Range: 20 to 250 volts in steps of 1 Default: 20...
Page 402 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 333: Direct inputs configuration settings The following settings are available all direct inputs. The settings shown below 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 403: Direct Outputs
CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Direct input states Select the Actual Values > Protection > Protection Inputs/Outputs > Direct Inputs menu item to open the direct input states window. Figure 334: Direct inputs states The following actual values are available for all direct inputs. The actual value shown below reflects direct input 1.
Page 404: Teleprotection Inputs And Outputs
PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 336: Direct output configuration settings The following settings are available for all direct outputs. The default values shown correspond to direct output 1. Direct Input 1 Operand Range: any FlexLogic™ operand Default: Off This setting specifies the FlexLogic™...
Page 405 CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 337: Teleprotection inputs and outputs processing Teleprotection input settings Select the Settings > Protection > Protection Inputs/Outputs > Teleprotection > Teleprotection Inputs menu item to open the teleprotection inputs configuration window. Figure 338: Teleprotection inputs configuration settings PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 406 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION 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 407: Using Shared Operands In Protection
CHAPTER 7: PROTECTION PROTECTION INPUTS AND OUTPUTS Figure 340: 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 408 PROTECTION INPUTS AND OUTPUTS CHAPTER 7: PROTECTION Figure 341: Default operand list by function The content of each operand list is dependent on the selected order code. The shared operands functionality expands upon this system. With this feature, an output Plus from any element can be assigned as a shared operand within the EnerVista UR Setup software.
Page 409: Protection Flexlogic
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ Figure 342: 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 on the >>...
Page 410 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION Plus Figure 343: 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 411 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 FlexLogic™).
Page 412: Protection Flexlogic™ Gates And Operators
PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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.
Page 413: Flexlogic™ Rules
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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.
Page 414 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION Figure 344: EnerVista Viewpoint Engineer typical view The Viewpoint Engineer compiler function can be used to check for problems with the logic once it has been created. Warning and error messages generated by the compiler are listed in the following tables.
Page 415: Protection Flexlogic™ Equation Editor
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ Table 26: Viewpoint Engineer compiler errors Message Description Affected operator Connection In not connected A connection-input symbol is not referencing an Connection input existing logic or math operator. Input not connected One or more of the inputs to an operator has no connection.
Page 416: Protection Flexlogic™ Timers
PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION Figure 345: Protection FlexLogic™ configuration settings A graphical representation of the protection FlexLogic™ can be displayed by clicking on the View button at the top of the equation. Figure 346: Typical protection FlexLogic™ display Protection FlexLogic™ timers There are 32 identical protection FlexLogic™...
Page 417: Non-Volatile Latches
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 will not reset upon reboot after the relay is powered down.
Page 418: Protection Flexelements
PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION Table 28: Non-volatile latch operation table Type Latch operation Reset Reset-dominant Previous state Previous state Set-dominant Previous state Previous state The logic for protection non-volatile latches is shown below. Figure 349: Non-volatile latches scheme logic Protection FlexElements™...
Page 419 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ Figure 350: 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 may be assigned to a FlexElement™...
Page 420 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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. Sample applications for the absolute input mode include monitoring the angular difference between two phasors with a symmetrical limit angle in both directions, monitoring power regardless of its direction, or monitoring a trend regardless of whether the signal increases of decreases.
Page 421 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ Figure 351: 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 422 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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.
Page 423: Customizing The Protection Flexlogic™ Operands
CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 424: Protection Flexlogic™ Operands
PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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 425 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 426 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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 427 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 428 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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 429 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 430 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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 431 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 432 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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 433 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 434 PROTECTION FLEXLOGIC™ CHAPTER 7: PROTECTION 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 435 CHAPTER 7: PROTECTION PROTECTION FLEXLOGIC™ 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 436: Protection Flexanalog™ Parameters
PROTECTION FLEXANALOG™ PARAMETERS CHAPTER 7: PROTECTION 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 437 CHAPTER 7: PROTECTION PROTECTION FLEXANALOG™ PARAMETERS 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™...
Page 438 PROTECTION FLEXANALOG™ PARAMETERS CHAPTER 7: PROTECTION PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 439: Automation
Plus Line Distance Protection System Chapter 8: Automation Automation Plus This section describes how to program the D90 automation features. Automation controller overview Plus The D90 automation controller allows the user to easily implement a variety of custom automation schemes. The controller can access both digital and analog inputs and outputs.
Page 440: Input And Output Structure
AUTOMATION CONTROLLER OVERVIEW CHAPTER 8: AUTOMATION Input and output structure Plus The input and output structure of the D90 is shown below. 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 is normally 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 breaker control logic is shown in the following figures. Figure 358: Breaker control logic, sheet 1 of 3 PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 444: Breaker Interlocking
BREAKERS CHAPTER 8: AUTOMATION Figure 359: Breaker control logic, sheet 2 of 3 Figure 360: 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 361: 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 breaker interlocking logic is shown below. Figure 362: 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 363: 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 365: Disconnect scheme logic, sheet 2 of 4 Figure 366: Disconnect scheme logic, sheet 3 of 4 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 451: Disconnect Control
CHAPTER 8: AUTOMATION DISCONNECTS Figure 367: Disconnect scheme 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 368: 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 370: Disconnect control logic, sheet 2 of 3 Figure 371: 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 372: 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 373: Disconnect interlocking logic Automation control This section describes the control elements used for automation. Front panel status and control There can be a maximum of breakers and disconnect switches (referred to as devices) plus autoreclose and local-remote status and control.
Page 457 CHAPTER 8: AUTOMATION AUTOMATION CONTROL Figure 374: 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 in 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 376: Breaker 1 status substituted The following indications are provided for breakers and disconnects. Figure 377: 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, etc.).
Page 459 CHAPTER 8: AUTOMATION AUTOMATION CONTROL Figure 378: 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 379: Local-remote control scheme 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 which are to be joined by the closure of a circuit breaker. The synchrocheck elements are typically 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 will block 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 will 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 381: Synchrocheck scheme logic, sheet 1 of 2 Figure 382: Synchrocheck scheme 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 is intended to replace 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 383: Time-out mode PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 467 CHAPTER 8: AUTOMATION AUTOMATION CONTROL Figure 384: Acknowledge mode Selector switch settings Select the Settings > Automation > Control > Selector Switches menu item to open the selector switch configuration window. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 468 AUTOMATION CONTROL CHAPTER 8: AUTOMATION Figure 385: 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 will change 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....Selector 1 changed its position to 7. SELECTOR 1 STP ALARM ..The selector position pre-selected via the stepping up control input has not been confirmed before the time out.
Page 472 AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION Figure 387: Automation virtual inputs configuration settings The following settings are available for each automation virtual input. The default values shown are for virtual input 1. Function Range: Enabled, Disabled Default: Disabled If this setting is “Disabled”, the virtual input will be 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 388: Automation virtual input logic Automation virtual outputs There are 255 virtual outputs that may 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 390: Automation virtual output programming example Contact input and output default assignment When a new settings file is created, the available contacts are automatically assigned 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 391: Contact input and output assignments All available contact inputs and output 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 392: 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 above).
Page 477 CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS When the input detects a voltage decrease, the input circuitry will draw 10 mA of current. If the voltage decrease is due to a state change then the voltage will quickly decrease, 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 Table 32: Nominal voltage setting for typical battery voltages Nominal voltage Validation threshold 24 V 20 V 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 will trigger an event in the sequence of events recorder.
Page 479: Contact Outputs
CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS The following settings are applied to all available protection and automation contact inputs. 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 time window that the relay contacts are monitored for contact input state changes.
Page 480 AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION Seal-In Range: any automation logic operand or shared operand Default: OFF This setting selects an operand (virtual output, element state, contact input, or virtual input) that will seal-in the contact output when asserted. Voltage Threshold Range: 20 to 250 volts in steps of 1 Default: 20...
Page 481: Virtual Analog Outputs
CHAPTER 8: AUTOMATION AUTOMATION INPUTS AND OUTPUTS Figure 398: Trip seal-in scheme settings Virtual analog outputs There are 128 virtual analog outputs that may be assigned via automation logic. Virtual analog outputs are resolved in each pass through the evaluation of the automation logic equations.
Page 482 AUTOMATION INPUTS AND OUTPUTS CHAPTER 8: AUTOMATION • Digital fault recorder (DFR). • Metering. • Equipment manager. • Self-tests. • Front panel interface (HMI). However, it is often desirable for an output from an element within one function can be available to an element within another function.
Page 483: Automation Logic
CHAPTER 8: AUTOMATION AUTOMATION LOGIC Figure 401: 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 on the >>...
Page 484 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Plus Figure 402: 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 Figure 403: Latch used in automation logic About automation virtual outputs The automation virtual output syntax is shown in the following table. Table 35: Automation virtual output operators Syntax Description Assigns the previous automation logic operand to the corresponding VDO(1) VDO(96) automation virtual digital output.
Page 488 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Syntax Description Divide the first operand by the second operand. DIV(a, b) Return the power of e (the base of natural logarithms) value of the previous operand. Return the largest integer less than or equal to the operand. FLOOR Return the remainder of the first operand divided by the second 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 About editing operators The automation editing operators are shown in the following table. Table 38: Automation logic editing operators Syntax Description...
Page 490 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Figure 407: Using comparators to verify approximate equivalence About automation timers Plus Unlike earlier versions of the D90 , automation timers are implemented like gates or latches and not through the specific setting menus. Automation timers have the following syntax: TIMER (IN, PKP, DPO).
Page 491: Automation Logic Equation Editor
CHAPTER 8: AUTOMATION AUTOMATION LOGIC Figure 409: 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 will never be asserted (set to logic 1).
Page 492 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Figure 411: 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 412: 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 415: 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 416: 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 is also asserted if the tap changer remains between taps for more than ten seconds. The lockout is latched until manually reset.
Page 496 AUTOMATION LOGIC CHAPTER 8: AUTOMATION Figure 420: 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 421: 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 423: Maximum operations per hour alarm automation logic Customizing the automation logic operands Select the Settings > Configure FlexOperands menu item to open the user-configurable operands window. Figure 424: User-configurable automation logic operands window Plus The left side of this screen displays all operands that are currently available to the D90 The automation logic operands are displayed by selecting the Automation tree item.
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 will 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 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 The definitions listed below reflect the programmed source and element names, where applicable. 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...
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. Furthermore, effective equipment monitoring allows maintenance to be targeted towards the equipment in the greatest Plus need.
Page 504: Circuit Breaker Arcing
BREAKER MANAGEMENT CHAPTER 9: EQUIPMENT MANAGER Figure 425: Equipment manager block diagram Breaker management This section describes the breaker management features of the equipment manager. Circuit breaker arcing The breaker arcing function provides indications of the condition of the circuit breaker interrupter.
Page 505 CHAPTER 9: EQUIPMENT MANAGER BREAKER MANAGEMENT Figure 426: Breaker arcing current measurement Select the Settings > Equipment Manager > Breaker > Breaker Arcing menu item to open the breaker arcing current configuration window. Figure 427: Breaker arcing current configuration settings The following settings are available for each breaker arcing current element.
Page 506 BREAKER 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 is proportional to 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 428: Breaker arcing current logic Battery monitor The battery monitor function monitors 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 DC GND FLT..........Indicates a battery DC ground fault. Typical wiring for the battery monitor element is shown below. Figure 429: Battery monitor wiring diagram Battery monitor settings Select the Settings > Equipment Manager > Battery Monitor menu item to open the battery monitor configuration window.
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 The Equipment Manager
USING SHARED OPERANDS IN THE 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 battery monitoring logic is shown below. Figure 431: Battery monitor scheme logic Using shared operands in the equipment manager Plus...
Page 511: Shared Equipment Manager Operands
CHAPTER 9: EQUIPMENT MANAGER USING SHARED OPERANDS IN THE EQUIPMENT MANAGER Figure 432: Default operand list by function The content of each operand list is dependent on the selected order code. The shared operands functionality expands upon this system. With this feature, an output Plus from any element can be assigned as a shared operand within the EnerVista UR Setup software.
Page 512: Customizing The Equipment Manager Logic Operands
USING SHARED OPERANDS IN THE EQUIPMENT MANAGER CHAPTER 9: EQUIPMENT MANAGER Figure 433: Shared operands configuration window Plus The left side of this screen displays all D90 operands that are available to the equipment manager function as shared operands. Select any operands from the other five primary features by clicking on the >>...
Page 513: Equipment Manager Operands
CHAPTER 9: EQUIPMENT MANAGER USING SHARED OPERANDS IN THE EQUIPMENT MANAGER Figure 434: User-configurable equipment manager logic operands window Plus The left side of this screen displays all operands that are currently available to the D90 The equipment manager logic operands are displayed by selecting the Equipment Manager tree item.
Page 514: Equipment Manager Flexanalog™ Parameters
EQUIPMENT MANAGER FLEXANALOG™ PARAMETERS CHAPTER 9: EQUIPMENT MANAGER BAT MON HIGH VDC OP ......Asserted when the battery high DC voltage monitor operates. 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.
Page 515: Digital Fault Recorder
Plus Line Distance Protection System Chapter 10: Digital fault recorder Digital fault recorder The digital fault recorder captures detailed information regarding abnormal occurrences in Plus the power system. The information captured by the DFR is stored in the D90 in non- volatile memory and can be accessed through the front panel interface.
Page 516: Fault Report
FAULT REPORT CHAPTER 10: DIGITAL FAULT RECORDER Figure 435: Example 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 • The fault report feature is enabled. • The source for the fault report is properly configured. • The block trigger input is not asserted. • A record capture is not currently in progress. The Memory Available indication is green when less than 80% of the memory has been filled.
Page 518: Fault Type Determination
FAULT REPORT CHAPTER 10: DIGITAL FAULT RECORDER Each fault report is stored as a file, and the relay capacity is 15 files. An sixteenth (16th) trigger overwrites the oldest file. Individual fault report features store their files in the same memory space.
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 439: Fault report configuration settings The following settings are available for the fault report. 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™...
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 440: Fault locator scheme logic Transient recorder The transient recorder is designed to capture 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.
Page 523 CHAPTER 10: DIGITAL FAULT RECORDER TRANSIENT RECORDER Figure 441: Trigger and re-trigger sequence The length of a transient record is also 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 provides an indication that 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 Transient recorder settings Select the Settings > DFR > Transient Record menu item to open the transient recorder function configuration window. Figure 444: Transient recorder function settings The following settings are available. Function Range: Enabled, Disabled Default: Enabled This setting enables and disables the transient recorder function.
Page 526 TRANSIENT RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Sample Rate Range: 16, 32, 64, 128, or 256 samples per cycle, or OFF Default: 32 This setting selects the time-resolution of the transient record. A larger setting necessarily results in a shorter record length. Block Trigger Range: any FlexLogic™...
Page 527 CHAPTER 10: DIGITAL FAULT RECORDER TRANSIENT RECORDER Transient recorder digital channels Up to 128 digital channels may be assigned to the transient recorder. Each channel may be individually configured by clicking the digital channels Select button in the transient recorder window to open the transient recorder digital channels window. Figure 446: Digital channel configuration settings The following settings are available for each digital channel.
Page 528 TRANSIENT RECORDER CHAPTER 10: DIGITAL FAULT RECORDER When set to “Trigger/Re-Trigger” or “Re-Trigger Only”, the transient recorder will be re- triggered if the signal is still asserted at the end of the trigger period. The resulting record will contain fault data only. A re-trigger is re-generated at the end of a transient 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 529 CHAPTER 10: DIGITAL FAULT RECORDER TRANSIENT RECORDER High Triggering Range: Off, Trigger Only, Trigger/Re-Trigger, Re-Trigger Only Default: Off This setting selects the high triggering function for the analog channel. When set to “Trigger Only” or “Trigger/Re-Trigger”, the transient recorder will initiate data capture when the magnitude of the signal is greater than the value of the setting.
Page 530: Disturbance Recorder
DISTURBANCE RECORDER CHAPTER 10: DIGITAL FAULT RECORDER Figure 449: 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 continuously capturing pre-event data and storing this data in memory.
Page 531 CHAPTER 10: DIGITAL FAULT RECORDER DISTURBANCE RECORDER Figure 450: Trigger and re-trigger sequence The number of disturbance records is also user-configurable. The length of disturbance Plus records stored by the D90 can store is a function of the number of records and the Plus number of configured channels.
Page 532: Front Panel Indications
DISTURBANCE RECORDER CHAPTER 10: DIGITAL FAULT 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 provides an indication that the disturbance recorder is ready to capture data and has memory available.
Page 533: Disturbance Recorder Settings
CHAPTER 10: DIGITAL FAULT RECORDER DISTURBANCE RECORDER Figure 452: Disturbance recorder screen Disturbance recorder settings Select the Settings > DFR > Disturbance Record menu item to open the disturbance recorder function configuration window. Figure 453: Disturbance recorder function settings The following settings are available. Function Range: Enabled, Disabled Default: Disabled...
Page 534 DISTURBANCE 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 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 535 CHAPTER 10: DIGITAL FAULT RECORDER DISTURBANCE RECORDER Disturbance recorder digital channels Up to 32 digital channels may be assigned to the disturbance recorder. Each channel may be individually configured by clicking the digital channels Select button in the disturbance recorder window to open the disturbance recorder digital channels window. Figure 455: Digital channel configuration settings The following settings are available for each disturbance recorder digital channel.
Page 536 DISTURBANCE RECORDER CHAPTER 10: DIGITAL FAULT RECORDER When set to “Trigger/Re-Trigger” or “Re-Trigger Only”, the disturbance recorder will be re-triggered if the signal is still asserted at the end of the trigger period. The resulting record will contain 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 537 CHAPTER 10: DIGITAL FAULT RECORDER DISTURBANCE 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 538: Using Shared Operands In The Digital Fault Recorder
USING SHARED OPERANDS IN THE DIGITAL FAULT RECORDER CHAPTER 10: 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 458: Analog channel trigger logic Using shared operands in the digital fault recorder Plus Plus...
Page 539: Shared Digital Fault Recorder Operands
CHAPTER 10: DIGITAL FAULT RECORDER USING SHARED OPERANDS IN THE DIGITAL FAULT RECORDER Figure 459: Default operand list by function The content of each operand list is dependent on the selected order code. The shared operands functionality expands upon this system. With this feature, an output Plus from any element can be assigned as a shared operand within the EnerVista UR Setup software.
Page 540: Digital Fault Recorder Flexanalog™ Parameters
DIGITAL FAULT RECORDER FLEXANALOG™ PARAMETERS CHAPTER 10: DIGITAL FAULT RECORDER Figure 460: 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 on the >>...
Page 541 CHAPTER 10: DIGITAL FAULT RECORDER DIGITAL FAULT RECORDER FLEXANALOG™ PARAMETERS Fault Location [1]........Metered fault location from fault report 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...
Page 542 DIGITAL FAULT RECORDER FLEXANALOG™ PARAMETERS CHAPTER 10: DIGITAL FAULT RECORDER PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 543: Metering Metering Source
Plus Line Distance Protection System Chapter 11: Metering Metering Plus This section describes how to program the D90 metering features. Metering source Select the Settings > Metering > Metering Source menu item to open the metering source configuration window. Figure 461: 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 phasor measurement unit 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 both voltages and currents. When configuring communication and recording features of the phasor measurement unit, the user could 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 This setting specifies amount of post-filtering applied to raw synchrophasor...
Page 546: Phasor Measurement Unit Communications
PHASOR MEASUREMENT UNIT CHAPTER 11: METERING setting values are effectively added to the measured angles. Therefore, enter a positive correction of the secondary signal lags the true signal; and negative value if the secondary signal leads the true signal. Ia Angle, Ib Angle, Ic Angle, Ig Angle Range: –5.00 to 5.00°...
Page 547 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Figure 464: Phasor measurement unit communications configuration The following settings are available for the communication port on each phasor measurement unit. Type Range: None, Network Default: None This setting specifies the first communication port for transmission of the phasor measurement unit data.
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 phasor measurement unit (PMU) contains five triggering mechanisms to facilitate triggering of the associated PMU recorder and cross-triggering of other PMUs of...
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 either phase voltages, auxiliary voltage, phase currents and ground current, in this hierarchy, depending on the source configuration as per Plus 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 phasor measurement unit frequency triggering function. Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of phasor measurement unit 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 phasor measurement unit 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 phasor measurement unit source.
Page 553 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Figure 470: Voltage triggering scheme logic Current triggering This phasor measurement unit current triggering function responds to elevated current. The trigger responds to the phase current signal of the phasor measurement unit source. All current channel (A, B, and C) are processed independently and could 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 may be used to extend the trigger after the situation returned 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 473: Power triggering configuration settings The following settings are available for each phasor measurement unit. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the phasor measurement unit power triggering function. Active Range: 0.250 to 3.000 pu in steps of 0.001 Default: 1.250 pu...
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 may be used to extend the trigger after the situation returned 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 557 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Figure 475: Frequency rate of change triggering configuration settings The following settings are available for each phasor measurement unit. Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the phasor measurement unit frequency rate of change triggering function.
Page 558: Phasor Measurement Unit Recording
PHASOR MEASUREMENT UNIT CHAPTER 11: METERING The logic for the phasor measurement unit frequency rate of change triggering function is shown below. Figure 476: Phasor measurement unit frequency rate of change triggering logic Phasor measurement unit recording Each logical phasor measurement unit (PMU) is associated with a recorder. The triggering condition is programmed via the Settings >...
Page 559 CHAPTER 11: METERING PHASOR MEASUREMENT UNIT Figure 478: Phasor measurement unit recording configuration settings The following settings are available for each phasor measurement unit. 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 481: Phasor measurement unit reporting over network configuration settings The following settings are available for each phasor measurement unit.
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 phasor measurement unit. 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™...
Page 564 PHASOR MEASUREMENT UNIT CHAPTER 11: METERING Function Range: Enabled, Disabled Default: Disabled This setting enables and disables the phasor measurement unit 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...
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 When the phasor measurement unit one-shot feature is enabled, the Plus...
Page 566: Data Logger
DATA LOGGER CHAPTER 11: METERING same IRIG-B signal: either the same GPS receiver or IRIG-B generator. Otherwise, the setpoints of the test set and the phasor measurement unit measurements should not be compared as they are referenced to different time scales. Figure 484: Testing synchrophasor measurement accuracy Collecting synchronized measurements ad hoc The phasor measurement unit one-shot feature can be used for ad hoc collection of...
Page 567 CHAPTER 11: METERING DATA LOGGER Figure 485: 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 will block data logger functionality.
Page 568: Data Logger Channel Configuration
DATA LOGGER CHAPTER 11: METERING Figure 486: Data logger scheme logic Data logger channel configuration Select the Settings > Metering > Data Logger > Channel Configuration menu item to open the data logger configuration window. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 569 CHAPTER 11: METERING DATA LOGGER Figure 487: 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 488: 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) 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 examples above are illustrated in the following figure. Figure 490: Measurement convention for symmetrical components Phase current metering Select the Actual Values >...
Page 575 CHAPTER 11: METERING METERED VALUES Figure 491: Phase current metering window The following actual values are available 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 item to open the metered ground current window. Figure 492: Ground current metering window The following actual values are available 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. Refer to Observing current and voltage phasors on page 571.
Page 578: Power Metering
METERED VALUES CHAPTER 11: METERING Figure 494: Auxiliary voltage metering window The following actual values are available 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 are available 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 item 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 item to open the metering commands menu. The commands in this window allow the user to clear accumulated metering values. Figure 499: Metering commands window The following commands are available.
Page 582 OBSERVING CURRENT AND VOLTAGE PHASORS CHAPTER 11: METERING Figure 500: Example 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: <Empty> 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 501: Default operand list by function The content of each operand list is dependent on the selected order code. The shared operands functionality expands upon this system. With this feature, an output Plus from any element 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 502: 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 on the >>...
Page 586: Metering Logic Operands
USING SHARED OPERANDS IN METERING CHAPTER 11: METERING Figure 503: 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 selecting the Metering tree item. 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 FREQ TRIGGER ......Asserted when the abnormal frequency trigger of phasor measurement unit 1 operates. 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.
Page 588 METERING FLEXANALOG™ PARAMETERS CHAPTER 11: METERING PMU 1 I2 Mag ..........Metered negative-sequence current magnitude for phasor measurement unit 1 PMU 1 I2 Ang ..........Metered negative-sequence current angle for phasor measurement unit 1 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...
Page 589 CHAPTER 11: METERING METERING FLEXANALOG™ PARAMETERS SRC 1 I0 Mag..........Metered zero-sequence current magnitude for source 1 SRC 1 I1 Angle ..........Metered positive-sequence current angle for source 1 SRC 1 I1 Mag..........Metered positive-sequence current magnitude for source 1 SRC 1 I2 Angle ..........Metered negative-sequence current angle for source 1 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.
Page 590 METERING FLEXANALOG™ PARAMETERS CHAPTER 11: METERING SRC 1 Vbc Angle.........Metered phase B to C voltage angle for source 1 SRC 1 Vbc Mag..........Metered phase B to C voltage magnitude for source 1 SRC 1 Vca Angle.........Metered phase C to A voltage angle for source 1 SRC 1 Vca Mag..........Metered phase A to A voltage magnitude for source 1 SRC 1 Vx RMS..........Metered RMS auxiliary voltage for source 1 SRC 1 Vx Angle..........Metered auxiliary voltage angle for source 1...
Page 591: Local Interface
Plus Line Distance Protection System Chapter 12: Local interface Local interface Plus This section describes 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 functionality with an optional second LCD display for front panel 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 is a color, TFT panel located that emulates the functionality found in a conventional annunciator unit. The annunciator provides indications on the status of system alarm points and actual values. It also displays self-test messages and product information for the unit.
Page 593: Annunciator Configuration
CHAPTER 12: LOCAL INTERFACE ANNUNCIATOR PANEL Figure 506: Annunciator alarm sequence The annunciator states are described in the following table. Table 44: Acknowledgeable alarm states Sequence (initial Process (status) Pushbutton Sequence (final Visual indication state) (input) state) Normal Normal Normal Abnormal Alarm Fast flash...
Page 594 ANNUNCIATOR PANEL CHAPTER 12: LOCAL INTERFACE Figure 507: Annunciator configuration page The following settings are available to configure the annunciator. The settings 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™...
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 509: Annunciator navigation dialog If the Use Default check box is selected and the Default Page is set to “None”, selection of...
Page 597 CHAPTER 12: LOCAL INTERFACE ANNUNCIATOR PANEL Figure 510: Metering value properties This dialog box allows the user to configure metering values. 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 512: 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 513: Mimic diagram editor dynamic symbols A maximum of 1010 dynamic components is allowed for each mimic diagram. When a dynamic symbol is selected and added to the diagram, a window will appear to configure the device.
Page 601: Metering Blocks
CHAPTER 12: LOCAL INTERFACE MIMIC DIAGRAM EDITOR Figure 515: Mimic diagram editor static symbols For more information on these symbols, please refer to the ANSI/IEEE 315A and IEC 617 standards. There is no limit on the number of static symbols per screen, provided they fit within the screen dimensions.
Page 602 MIMIC DIAGRAM EDITOR CHAPTER 12: LOCAL INTERFACE Figure 517: Mimic diagram metering block symbol The properties of a metering block can be configured by right-clicking on the box and selecting the Properties item to open the Metering Properties configuration window. Figure 518: Metering properties window The following items 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 The overview mode provides a preview of how the mimic diagram will appear on the overview screen of the front panel interface. The control mode provides a preview of how the mimic diagram will appear on the control screen of the front panel interface.
Page 605 CHAPTER 12: LOCAL INTERFACE MIMIC DIAGRAM EDITOR Figure 521: Pre-configured mimic diagram 1 (breaker-and-a-half scheme) Figure 522: Pre-configured mimic diagram 2 (breaker-and-a-half scheme with breaker disconnects) Figure 523: Pre-configured mimic diagram 3 (breaker-and-a-half scheme, with breaker and line disconnects) Figure 524: 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 525: Pre-configured mimic diagram 5 (breaker-and-a-half scheme with line disconnect) Figure 526: 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 527: Pre-configured mimic diagram 7 (double-bus bypass scheme 1) Figure 528: Pre-configured mimic diagram 8 (double-bus bypass scheme 2) Figure 529: 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 530: Pre-configured mimic diagram 10 (single-bus scheme) Figure 531: Pre-configured mimic diagram 11 (single-bus scheme with line disconnect) Figure 532: 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 533: Metering summary editor window When the user clicks the left mouse button in a metering location, the dialog shown below appears. The user can 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 534: Metering configuration window Text Range: up to 20 alphanumeric characters Default: --- This setting defines the selected metering cell as a text box. These are typically used as headings. Specify up to 10 alphanumeric characters. Parameter Range: any FlexAnalog™...
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 method of entering 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 Pushbuttons Settings
CHAPTER 12: LOCAL INTERFACE USER-PROGRAMMABLE PUSHBUTTONS User-programmable pushbuttons settings Select the Settings > Local HMI > User-Programmable Pushbuttons menu item to open the user-programmable pushbuttons settings window. Figure 535: User-programmable pushbuttons 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 is applicable only if 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 the latched mode.
Page 615 CHAPTER 12: LOCAL INTERFACE USER-PROGRAMMABLE PUSHBUTTONS Figure 536: User-programmable pushbutton logic, sheet 1 of 2 PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 616: User-Programmable Pushbuttons Editor
USER-PROGRAMMABLE PUSHBUTTONS CHAPTER 12: LOCAL INTERFACE Figure 537: User-programmable pushbutton logic, sheet 2 of 2 User-programmable pushbuttons editor Select the Settings > Local HMI > User-Programmable Pushbuttons Editor menu item to open the user-programmable pushbuttons editor window. Figure 538: User-programmable pushbuttons editor settings Click the Configure button to access the pushbutton configuration settings.
Page 617 CHAPTER 12: LOCAL INTERFACE USER-PROGRAMMABLE PUSHBUTTONS Figure 539: Pushbutton configuration window 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 only 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 describes 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 user password security access levels: command and setting.
Page 620: Password Security Settings
PASSWORD SECURITY CHAPTER 13: SECURITY When entering a settings or command password via Ethernet or the serial USB interface, the user must enter the corresponding password level shown in the following table. Table 45: Required password levels for various connection types Connection type Password required Front panel USB...
Page 621 CHAPTER 13: SECURITY PASSWORD SECURITY Remote Command Password Range: up to 12 visible ASCII characters (see restrictions above) Default: null The value of the remote 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 Operation
PASSWORD SECURITY CHAPTER 13: SECURITY Password Access Events Range: Enabled, Disabled Default: Disabled This setting enables and disables the logging of password access supervision events in the sequence of events recorder. The dual permission security access feature provides a mechanism for customers to prevent unauthorized or unintended upload of settings to a device through the local or remote interfaces.
Page 623: Enervista Security Management System
CHAPTER 13: SECURITY ENERVISTA SECURITY MANAGEMENT SYSTEM Plus The D90 provides a means to raise an alarm upon failed password entry. Should password verification fail while accessing a password-protected level of the relay (either settings or commands), the operand is asserted. The operand can be UNAUTHORIZED ACCESS programmed to raise an alarm via contact outputs or communications.
Page 624: Modifying User Privileges
ENERVISTA SECURITY MANAGEMENT SYSTEM CHAPTER 13: SECURITY • The user adding the new user must have administrator rights. • The EnerVista security management system must be enabled. Select the Security > User Management menu item to open the user management configuration window.
Page 625 CHAPTER 13: SECURITY ENERVISTA SECURITY MANAGEMENT SYSTEM • The EnerVista security management system must be enabled. Select the Security > User Management menu item to open the user management configuration window. Locate the username in the User field. Modify the user access rights by checking or clearing one or more of the fields shown. Field Description Delete Entry...
Page 626 ENERVISTA SECURITY MANAGEMENT SYSTEM CHAPTER 13: SECURITY PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 627: Testing
Plus Line Distance Protection System Chapter 14: Testing Testing Plus This section describes the D90 testing features. Test mode Plus The D90 provides test settings to verify that functionality using simulated conditions for contact inputs and outputs. To initiate the test mode, the setting must Test Mode Function be “Enabled”...
Page 628: Force Contact Outputs
TEST MODE CHAPTER 14: TESTING Figure 541: Force contact inputs configuration settings The following settings are available. Test Mode Function Range: Enabled, Disabled Default: Disabled This setting enables and disabled the test mode functionality. Test Mode Initiate Range: any FlexLogic™ operand Default: ON The test mode will initiate when the operand assigned to this setting is logic 1.
Page 629: Self-Tests
CHAPTER 14: TESTING SELF-TESTS Figure 542: Force contact outputs configuration settings The following settings are available. Test Mode Function Range: Enabled, Disabled Default: Disabled This setting enables and disabled the test mode functionality. Test Mode Initiate Range: any FlexLogic™ operand Default: ON The test mode will initiate 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 of these messages appear, contact GE Grid Solutions. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 631 AC SLOT J NOT CALIBRATED Description: The AC module in the indicated slot is not properly calibrated. Severity: Device is temporarily out-of-service. If either of these messages appear, first reset the alarm. If the alarm recurs, contact GE Grid Solutions. 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, first reset the alarm. If the alarm recurs, contact GE Grid Solutions. IO SLOT E TROUBLE...
Page 633 CHAPTER 14: TESTING SELF-TESTS UNIT NOT PROGRAMMED Description: The unit is configured as not programmed. Severity: Protection is not available If this message appears, confirm that the unit has the proper settings. Change the Relay Settings value to “Programmed”. The minor self-test error messages are indicated in yellow on the annunciator display and are described below.
Page 634 If this message appears, check that the voltage at the power supply input is within limits. If OK, check that the 48 volt supply is healthy. If not OK, contact GE Grid Solutions. PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 635: Self-Test Logic Operands
CHAPTER 14: TESTING SELF-TESTS REMOTE DEVICES OFF Description: A remote device is specified in the configuration for GOOSE messaging but is not connected to the network. Severity: Protection is available. GOOSE messaging with the offline device is not available. If this message appears, check that all devices that are specified for GOOSE messaging are connected to the network, are functioning properly, and are correctly configured.
Page 636 SELF-TESTS CHAPTER 14: TESTING FRONT PANEL MISMATCH.......Asserted when the FRONT PANEL MISMATCH self-test error message is issued. HIGH TEMPERATURE.........Asserted when the HIGH TEMPERATURE self-test error message is issued. IO SLOT E FMW MSMTCH......Asserted when the IO SLOT E FIRMWARE MISMATCH self-test error message is issued.
Page 637: Theory Of Operation
Plus Line Distance Protection System Chapter 15: Theory of operation Theory of operation Plus This section describes the basic theoretical principles behind the operation of D90 Plus The D90 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.
Page 638: Distance Element Time Domain Algorithm
Plus THE D90 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
Plus CHAPTER 15: THEORY OF OPERATION THE D90 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
Plus THE D90 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...
Page 641 Plus CHAPTER 15: THEORY OF OPERATION THE D90 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 Plus THE D90 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 below.
Page 643 Plus CHAPTER 15: THEORY OF OPERATION THE D90 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 independently adjusted from the mho and reactance comparators.
Page 644 Plus THE D90 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 below.
Page 645 Plus CHAPTER 15: THEORY OF OPERATION THE D90 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...
Page 646: Memory Polarization
Plus THE D90 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 ×...
Page 647: Distance Elements Analysis
Plus CHAPTER 15: THEORY OF OPERATION THE D90 DISTANCE ELEMENTS Figure 549: Dynamic shift of the memory-polarized quadrilateral characteristic Mutual zero-sequence compensation may raise concerns regarding directional integrity on reverse faults in the situation when the relay gets overcompensated. This problem does Plus not affect the D90 because its ground distance elements use zero-sequence and...
Page 648 Plus THE D90 DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION Figure 550: 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.
Page 649 Plus CHAPTER 15: THEORY OF OPERATION THE D90 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 Plus THE D90 DISTANCE ELEMENTS CHAPTER 15: THEORY OF OPERATION Plus When memory expires, the D90 will use 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 Plus CHAPTER 15: THEORY OF OPERATION THE D90 DISTANCE ELEMENTS Table 20: Mho phase AB element conditions Parameter Condition Supervision Overcurrent supervision | (I – I ) / √3 | > | ∠((I )) – ∠((V Comparator Limit Mho difference angle –...
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 551: 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 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 552: 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 above is a correct measure of the distance from the VT location to the fault.
Page 658: Ground Directional Overcurrent Example
SERIES COMPENSATED LINES 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. 81 For the reverse-looking element: Eq.
Page 659: Memory Polarized Directional Comparators
CHAPTER 15: THEORY OF OPERATION SERIES COMPENSATED LINES Voltage or current inversion may lead to false direction discrimination by directional elements. This may potentially include both a failure to operate on a forward in-zone fault as well as misoperation on a reverse fault. Both distance and overcurrent directional elements can be affected.
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 may be addressed in the D90 in a traditional way by shortening the reach of an underreaching distance elements 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 555: Dynamic reach, low-current external fault The following figure illustrates a high-current external fault. The air gaps or MOVs conduct majority of the fault current and neither steady-state nor transient overreach takes place. The relay does not reduce its reach as it is not necessary.
Page 662: Single-Pole Tripping
SINGLE-POLE TRIPPING CHAPTER 15: THEORY OF OPERATION Figure 557: 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;...
Page 663 CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING Figure 558: 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 will issue a single-pole trip. It is assumed that when tripping three-poles both the zone 1 and the POTT shall 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 pickup 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 If the fault evolves slowly, the sequence is different: The relay trips phase A as in the previous example. The phase selector resets, the open pole detector is activated and forces the zone 1 and zone 2 AG, AB, CA and negative-sequence overcurrent elements to reset.
Page 667: Communications Channels For Pilot-Aided Schemes
CHAPTER 15: THEORY OF OPERATION SINGLE-POLE TRIPPING The pre-fault quantities are captured and the calculations start when the disturbance detector (ANSI 50DD) operates. 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 its output operands and ignores any subsequent operations of the...
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 fault data is coded as shown in the following tables. 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 Phase selector determination of fault type Bit pattern AB, ABG, BC, BCG, CA, CAG, 3P, or unrecognized Table 41: Blocking scheme transmit codes for four-bit channels Phase selector determination of fault type Bit pattern Operands asserted STOP STOP...
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 will force 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: Maintenance
Plus Line Distance Protection System Chapter 16: Maintenance Maintenance This section outlines maintenance, repair, storage, and disposal of the hardware and software. General maintenance The unit requires minimal maintenance. As a microprocessor-based relay, its characteristics do not change over time. Back up and restore settings This section describes how to backup settings to a file and how to use that file to restore the settings to the original unit or to a replacement unit.
Page 680: Restore Settings
UPGRADE SOFTWARE CHAPTER 16: MAINTENANCE To save a settings file in the URS format in EnerVista Offline Window: In EnerVista, right-click in the Offline Window area and select New Settings File. A window opens. Change the file name at the end of the Path field, keeping the .urs extension. Plus From the Associate File with Device drop-down list, select the D90 device.
Page 681: Upgrade Firmware
CHAPTER 16: MAINTENANCE UPGRADE FIRMWARE After upgrading, check the version number under Help > About. If the new version does not display, try uninstalling the software and reinstalling the new versions. You can also downgrade the software; use the same procedure here. Plus A message can display in the EnerVista software when accessing a D90 device that the...
Page 682: Uninstall And Clear Files And Data
Customers are responsible for shipping costs to the factory, regardless of whether the unit is under warranty. • Fax a copy of the shipping information to the GE Grid Solutions service department in Canada at +1 905 927 5098. Use the detailed return procedure outlined at https://www.gegridsolutions.com/multilin/support/ret_proc.htm...
Page 683: Disposal
CHAPTER 16: MAINTENANCE DISPOSAL Disposal There are no special requirements for disposal of the unit at the end its service life. To prevent non-intended use of the unit, remove interior modules, dismantle the unit, and recycle the metal when possible. PLUS LINE DISTANCE PROTECTION SYSTEM –...
Page 684 DISPOSAL CHAPTER 16: MAINTENANCE PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 685: Appendix
Warranty For products shipped as of 1 October 2013, GE Grid Solutions warrants most of its GE manufactured products for 10 years. For warranty details including any limitations and disclaimers, see the GE Grid Solutions Terms and Conditions at http://gegridsolutions.com/multilin/warranty.htm...
Page 686 REVISION HISTORY CHAPTER 17: APPENDIX PLUS LINE DISTANCE PROTECTION SYSTEM – INSTRUCTION MANUAL...
Page 687 Plus Line Distance Protection System Index Automation virtual analog outputs description ..................... 471 settings ....................471 AC modules Automation virtual inputs connections ..................... 54 description ..................... 461 description .................... 170 logic ......................462 Altitude ......................46 settings ....................461 Annunciator specifications ..................37 operation ..................73, 582 Automation virtual outputs...
Page 688 INDEX Auxiliary undervoltage Breaker interlocking description .................... 270 description .....................434 logic ......................271 logic ......................436 operands ....................415 operands ....................488 settings ....................270 settings ....................434 specifications ..................26 specifications ..................38 Backup ......................669 Cautions ......................1 Battery monitor Certifications ..................45, 46 description ....................
Page 689 INDEX Directional comparison blocking Energy metering description .................... 302 overview ....................23 logic ......................306 specifications ..................39 operands ....................417 Equipment manager settings ....................303 description ..................... 493 Directional comparison unblocking front panel interface ................73 description .................... 307 operands ....................503 logic ......................
Page 690 INDEX Force contact inputs IEC 61850 ................617 Force contact outputs actual values ............135, 136, 137, 138 ............... 618 DNA assignments ................117 Frequency metering GGIO1 settings ..................129 specifications ..................39 GGIO2 settings ..................130 Front panel HMI GGIO4 settings ..................130 specifications ..................41 GGIO5 settings ..................132 Front panel interface GSSE/GOOSE configuration ............109...
Page 691 INDEX Metering logic Neutral overvoltage operands ....163, 164, 426, 491, 504, 530, 576, 577, 625 description ..................... 267 Mimic diagram logic ......................268 operands ....................420 settings ....................594 settings ....................267 MMXU deadbands ................127 specifications ..................32 Modbus protocol Neutral time overcurrent settings ....................
Page 692 INDEX Phase instantaneous overcurrent POTT description .................. 235, 236 description .....................293 operands ....................422 logic ......................297 settings ....................235 operands ....................424 specifications ..................35 settings ....................293 Phase overvoltage Power cut-off level ................174 description .................... 265 Power metering logic ......................266 specifications ..................39 operands ....................
Page 693 INDEX PUTT Setting groups description .................... 291 FlexLogic control ................321 logic ......................292 operands ....................426 operands ....................425 settings ....................320 settings ....................291 Setting templates editing ......................79 enabling .....................78 introduction .....................77 removing ....................81 Real time clock security ......................80 operands ....................
Page 694 INDEX Test mode Voltage elements ..................262 force contact inputs ................. 617 Voltage inputs force contact outputs ..............618 settings ....................172 overview ....................617 Voltage metering TFTP protocol operands ....................579 settings ......................94 specifications ..................39 Time overcurrent curves VT fuse failure definite time curve ................232 description .....................330 FlexCurves .....................

GE D90 Plus Instruction Manual

1 Getting Started

Introduction to the UR Plus -Series

Enervista Software

2 Product Description

Order Codes

Specifications

3 Installation

Physical Installation

Electrical Installation

4 Interfaces

Front Panel Overview

5 Enervista Software Suite

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

Battery Monitor

Using Shared Operands in the Equipment Manager

Equipment Manager Flexanalog™ Parameters

10 Digital Fault Recorder

Fault Report

Transient Recorder

Disturbance Recorder

Using Shared Operands in the 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

14 Testing

Test Mode

Self-Tests

15 Theory of Operation

Plus Distance Elements

Phase Distance Applied to Power Transformers

Ground Directional Overcurrent Theory

Series Compensated Lines

Single-Pole Tripping

16 Maintenance

Quick Links

Related Manuals for GE D90 Plus

Summary of Contents for GE D90 Plus