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1KHA000835-UEN en RE.316 4 Numerical Protection and Control Unit - Operating Instructions (Edition...
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1KHA000835-UEN Edition October 2004 RE.316*4 Numerical Protection and Control Devices Operating Instructions
Transcript of 1KHA000835-UEN en RE.316 4 Numerical Protection and Control Unit - Operating Instructions (Edition...
RE.316*4Numerical Protection and Control Devicesp Operating Instructions
1KHA000835-UENEdition October 2004
2004 ABB Switzerland Ltd Baden 1st Edition Applies for software version V6.4 and higher
All rights with respect to this document, including applications for patent and registration of other industrial property rights, are reserved. Unauthorized use, in particular reproduction or making available to third parties without our explicit consent in writing is prohibited. The use is only allowed for the purpose laid down in the contract. This document has been carefully prepared and reviewed. Should in spite of this the reader find an error, he is requested to inform us at his earliest convenience. The data contained herein purport solely to describe the product and are not a warranty of performance or characteristic. It is with the best interest of our customers in mind that we constantly strive to improve our products and keep them abreast of advances in technology. This may, however, lead to discrepancies between a product and its 'Technical Description' or 'Operating Instructions'.
Version 6.4 and higher
1. Introduction 2. Description of hardware
3. Setting the functions
4. Description of function and application
5. Operation (CAP2/316)
6. Self-testing and diagnostics
7. Installation and maintenance
8. Technical data
9. Interbay bus (IBB) interface
10. Supplementary information
12. Appendices
How to use the Operating Instructions for the RE.316*4 V6.4 and higherWhat do you wish to know about the device ...* General theoretical familiarisation
What precisely?Brief introduction General overview Technical data Hardware Software
Look in the following Chapter (C) / Sections (S): C 1 (Introduction) C 1, S 2.1. to S 7.1. (all Section summaries) C 8 (Data Sheet, CT requirements) C 2 (Description of hardware) C 3 (Setting the functions) C 4 (Description of function and application) C 6 (Self-testing and diagnostics) C 10 (Software changes) S 7.2.1. S 7.3.1. C 12 (Wiring diagram), S 7.3., S 7.4. to S 7.5.5. C 9 (IBB) S 9.6. (IBB address list) S 5.2.2. S 5.2.3. to S 5.2.4.2., S 7.5.1. S 3.2. to S 3.4., S 5.3., S 5.4., S 5.9. S 3.5. to S 3.8., S 5.3., S 5.4., S 5.9. S 5.2.4.3. S 7.4.6. to S 7.4.10. S 5.5.3. S 7.5.6. S 5.5.4., S 7.6.1. S 7.7. S 7.8. S 5.5.1. S 3.7.4., S 5.5.5. S 5.5.2. S 5.10.
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How to install and connect it
Checks upon receipt Location Process connections Control system connections
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How to set and configure it
Installing the HMI Starting the HMI Configuration Setting functions Quitting the HMI Checking the connections Functional test Commissioning checks Fault-finding Updating software Adding hardware Sequential recorder Disturbance recorder Measurements Local Display Unit
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How to check, test and commission it
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How to maintain it
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How to view and transfer data
RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
October 2004
1.1.1. 1.2. 1.2.1. 1.2.2. 1.2.3. 1.3. 1.3.1. 1.3.2. 1.4. 1.4.1. 1.4.2. 1.5. 1.5.1. 1.5.2. 1.6. 1.6.1. 1.6.2.
INTRODUCTIONGeneral ..............................................................................................1-2 Safety instructions..............................................................................1-3 Safety instruction indications .............................................................1-3 General rules .....................................................................................1-3 General safety instructions ................................................................1-4 Line Protection REL316*4..................................................................1-5 Application .........................................................................................1-5 Main features .....................................................................................1-5 Transformer Protection RET316*4.....................................................1-8 Application .........................................................................................1-8 Main features .....................................................................................1-8 Generator Protection REG316*4 .....................................................1-10 Application .......................................................................................1-10 Main features ...................................................................................1-10 Control Device REC316*4 ...............................................................1-12 Application .......................................................................................1-12 Main features ...................................................................................1-12
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1.1.1.
INTRODUCTIONGeneral The following device types, the Line Protection REL316*4, the Transformer Protection RET316*4, the Generator Protection REG316*4 and the Control Device REC316*4 comprise the new generation of fully digital protection systems, i.e. the analog- process inputs are converted to digital values immediately after the input transformers and the resulting digital signals are processed exclusively by micro-processors. This Operating Instructions is valid for all four device types. The designation 'RE.316*4' is used as the identification for the device family in the following sections. Because of its compact design, the use of only a few different hardware units, modular software and continuous self-monitoring and diagnostic functions, the RE.316*4 family optimally fulfils all the demands and expectations of a modern protection scheme with respect to efficient economic plant management and technical performance. The AVAILABILITY, which is the ratio between fault-free operating time and total operational life, is certainly the most important requirement a protection device has to fulfil. As a result of continuous monitoring, this ratio in the case of RE.316*4 is almost unity. SIMPLICITY of operation, control and commissioning of the device are achieved by the compact design and the interactive, PC based configuration program CAP2/316. Absolute FLEXIBILITY of the RE.316*4 scheme, i.e. adaptability to a specific primary system or existing protection (retrofitting), is assured by the supplementary functions incorporated in the software and by the ability to assign inputs and outputs with the CAP2/316. Decades of experience in the protection and control have gone into the development of the RE.316*4 to provide the highest degree of RELIABILITY, DISCRIMINATION and STABILITY. Digital processing of all the signals endows the scheme with ACCURACY and constant SENSITIVITY throughout its useful life.
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1.2. 1.2.1.
Safety instructions Safety instruction indications The following symbols are utilised for safety instructions in this Operating Instructions. These apply to person and personal working with the devices as well as the environment. This could involve more than one device of this family.
DANGER: This symbol indicates immediate danger due to high electrical voltage, or a mechanical or other cause. Non-observance can lead to serious injury or even death.
WARNING: This symbol draws attention to a dangerous situation. Non-observance can lead to serious injury to persons or damage to property.
CAUTION ESD: This symbol indicates specific information for the avoidance of equipment damage due to electrostatic discharge. The constructional elements and modules may only be touched by persons who are earthed. CAUTION LASER/LED: This symbol indicates the use of a laser of Class Laser/LED in the product. You should therefore avoid any direct eye contact with the laser.
NOTICE: An important instruction that must be observed.
IMPORTANT: It must be ensured that no possibly damaging situation can arise for the product or for its surroundings.
1.2.2.
General rules The RE.316*4 devices incorporates the latest practices and guidelines and complies with the recognized safety rules. Nevertheless, care must always be taken to avoid danger.
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Only use the RE.316*4 devices when it is in perfect working order and in strict accordance with these Operating Instructions. Dangerous situations can arise if the equipment is used improperly, especially if the user changes the configuration. 1.2.3. General safety instructions DANGER: Live electrical equipment is in the immediate vicinity of RE.316*4. Before working on the system, always ensure that contact with, or proximity to live voltage parts are avoided. The device RE.316*4 can initiate operation of other electrical equipment (circuit-breakers and isolators). Before working on the device, always ensure that unwanted operations are inhibited or have no effect on personnel or equipment. Strictly observe all safety precautions (interlocks, locks and blocking devices), especially those issued for the specific station. WARNING: Only properly authorized, professionally qualified and correspondingly trained personnel, who have also read and understood the operating instructions, may work on the RE.316*4 device.
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1.3. 1.3.1.
Line Protection REL316*4 Application The REL316*4 numerical line protection scheme is designed for the high-speed discriminative protection of lines and cables in distribution and transmission systems. The rated voltage of the line being protected is not a restriction and the protection is applicable to solidly or low-resistance grounded systems, systems with Petersen coils or to ungrounded systems. REL316*4 is suitable for the protection of long or short overhead lines or cables, double-circuit lines, heavily loaded lines, lines with weak infeeds and what are referred to as 'short-zone' lines. All kinds of faults are detected including close-in three-phase faults, cross-country faults, evolving faults and high-resistance earth faults. REL316*4 takes power swings and reversal of fault energy into account. Switching onto an existing fault results in instantaneous tripping of the circuit-breaker. REL316*4 places relatively low requirements on the performance of CTs and VTs and is not dependent on their characteristics (CVTs are permissible). REL316*4 can operate with any kind of communications channel (PLC, optical fibers etc.) between the terminal stations.
1.3.2.
Main features REL316*4s library of protection functions includes the following: Distance protection with overcurrent or underimpedance starters (polygon characteristic) 5 distance stages (independently set polygon characteristics for forwards and reverse measurement) definite time overcurrent back-up protection (including "shortzone" protection) VT supervision power-swing blocking system logic for switch-onto-fault protection overreaching permissive underreaching transfer tripping (also for weak infeed and communications channel failure) permissive overreaching transfer tripping (also for weak infeed, communications channel failure and reversal of fault energy direction)
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blocking scheme (also for reversal of fault energy direction)
sensitive E/F protection for ungrounded systems E/F protection for grounded systems inverse time earth fault overcurrent protection overtemperature protection definite time over and undercurrent protection provision for inrush blocking inverse-time over/undercurrent protection (Current-Inv) directional definite time overcurrent protection directional inverse time overcurrent protection definite time over and undervoltage protection power protection synchrocheck. breaker failure protection longitudinal differential protection binary signal transmission. auto-reclosure supplementary logic functions such as logic timer delay contact bounce filter supplementary user logic programmed using CAP2/316 (function plan programming language FUPLA). This requires systems engineering.
REL316*4 includes the following communication channel functions:
REL316*4 includes the following logic functions:
The following measurement and monitoring functions are also provided: single-phase measuring function UIfPQ three-phase measurement module three-phase current plausibility three-phase voltage plausibility.
An event and disturbance recorder is integrated in the device (with information of fault distance converted to reference length).
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The allocation of the opto-coupler inputs, the LED signals and the auxiliary relay signal outputs, the setting of the various parameters, the configuration of the scheme and the display of the events and system variables are all performed interactively by means of the HMI. REL316*4 is equipped with serial interfaces for the connection of a local control PC and for remote communication with the station control system. REL316*4 is also equipped with continuous self-monitoring and selfdiagnostic functions. Suitable testing devices (e.g. the MODURES test set XS92b) are available for quantitative testing. REL316*4 can be semi-flush or surface mounted or can be installed in an equipment rack.
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1.4. 1.4.1.
Transformer Protection RET316*4 Application The digital transformer protection RET316*4 is designed for fast selective protection of two and three-winding power transformers. It can also be applied to the protection of autotransformers and generator/transformer units. The unit detects the following faults on power transformers: all phase faults earth faults where the power transformer star-point is solidly or low-impedance grounded inter-turn faults
The RET316*4 places only low requirements on main CT performance. 1.4.2. Main features RET316*4 can be supplied with a desired combination of the following protection functions. The functions are selected from the RE.216 / RE.316*4 library of function modules: The transformer differential protection function (Diff-Transf) is one of the most important and provides fast selective protection of all transformers with ratings above a few MVA. The thermal overload function (Overtemp) protects the insulation against damage due to excessively high temperatures. It is normally equipped with two independently set operating stages and is used especially where oil temperature monitors are not installed. definite time over and undercurrent protection (Current-DT) provision for inrush restraint peak value overcurrent protection (Current-Inst) inverse time-overcurrent protection (Current-Inv) directional definite time overcurrent protection (DirCurrentDT) directional inverse time overcurrent protection (DirCurrentInv) inverse definite minimum time overcurrent function (I0-Invers) definite time over and undervoltage protection (Voltage-DT)
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peak value overvoltage protection (Voltage-Inst) power function (Power) frequency function (Frequency) rate-of-change frequency protection (df/dt) definite time overfluxing (Overexcitat) inverse time overexcitation (U/F-Inv) distance protection (Distance) as backup protection for the power transformer and neighbouring lines breaker failure protection (BreakerFailure) supplementary logic functions such as supplementary user logic programmed with the aid of CAP2/316 (function plan programming language FUPLA). This requires systems engineering. logic delay counter (Count) contact bounce filter
The following measurement and monitoring functions are also provided: single-phase measuring function UIfPQ three-phase measurement module three-phase current plausibility three-phase voltage plausibility disturbance recorder
The device has an integrated event logger. The allocation of the opto-coupler inputs, the LED signals and the auxiliary relay signal outputs, the setting of the various parameters, the configuration of the scheme and the display of the events and system variables are all performed interactively by means of the HMI. RET316*4 is equipped with serial interfaces for the connection of a local HMI (PC) and for remote communication with the station control system. RET316*4 is also equipped with continuous self-monitoring and selfdiagnostic functions. Suitable testing devices (e.g. test set XS92b) are available for quantitative testing. RET316*4 can be semi-flush or surface mounted or can be installed in an equipment rack.
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1.5. 1.5.1.
Generator Protection REG316*4 Application The REG316*4 numerical generator protection has been designed for the high-speed discriminative protection of small and medium size generators. It can be applied to units with or without step-up transformer in power utility or industrial power plants. REG316*4 places relatively low requirements on the performance of CTs and VTs and is independent of their characteristics.
1.5.2.
Main features REG316*4s library of protection functions includes the following: generator differential transformer differential definite time over and undercurrent provision for inrush blocking (Current-Inst) (Imax-Umin) (Current-Inv) (DirCurrentDT) (DirCurrentInv) (NPS-DT) (NPS-Inv) (Voltage-DT) (Voltage-Inst) (Underimped) (MinReactance) (Power) (OLoad-Stator) (OLoad-Rotor) (Frequency) (df/dt) peak value overcurrent voltage-controlled overcurrent inverse time overcurrent directional definite time overcurrent protection directional inverse time overcurrent protection definite time NPS inverse time NPS definite time over and undervoltage peak value overvoltage underimpedance underreactance power protection stator overload rotor overload frequency rate-of-change frequency protection (Diff-Gen) (Diff-Transf) (Current-DT)
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overexcitation inverse time overexcitation voltage comparison overtemperature 100 % stator ground fault 100 % rotor ground fault pole slipping inverse time ground fault overcurrent breaker failure protection supplementary logic functions such as
(Overexcitat) (U/f-Inv) (Voltage-Bal) (Overtemp) (Stator-EFP) (Rotor-EFP) (Pole-Slip) (I0-Invers) (BreakerFailure)
supplementary user logic programmed using CAP2/316 (function plan programming language FUPLA). This requires systems engineering. logic timers metering debounce.
The following measuring and monitoring functions are also available: single-phase measuring function UIfPQ three-phase measurement module three-phase current plausibility three-phase voltage plausibility disturbance recorder
The device has an integrated event logger. The allocation of the opto-coupler inputs, the LED signals and the auxiliary relay signal outputs, the setting of the various parameters, the configuration of the scheme and the display of the events and system variables are all performed interactively by means of the HMI. REG316*4 is equipped with serial interfaces for the connection of a local control PC and for remote communication with the station control system. REG316*4 is also equipped with continuous self-monitoring and selfdiagnostic functions. Suitable testing devices (e.g. test set XS92b) are available for quantitative testing. REG316*4 can be semi-flush or surface mounted or can be installed in an equipment rack.
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1.6. 1.6.1.
Control Device REC316*4 Application The numerical control unit REC316*4 is designed to perform data acquisition, monitoring, and control functions in MV and HV substations. It is installed in the individual switchgear bays. The switchgear bay control unit can be configured for SF6 gasinsulated switchgear (GIS), for indoor and outdoor switchgear and for single, double or multiple busbar stations. REC316*4 registers and processes the switchgear position signals, the measured variables and the alarms occurring in a switchgear bay. The corresponding data are then made available to the station control level at the communication interface (IBB). REC316*4 receives control instructions from the station control level or from the local mimic, processes them in relation to the bay control logic and executes them. The interlocks included in the REC316*4 control device prevent inadmissible switching operations, which could cause damage to plant or endanger personnel. REC316*4 checks the synchronisation on both sides of the circuitbreaker before enabling the close command. A frequency protection function is integrated in REC316*4, which enables intelligent load shedding. REC316*4 also provides facility for adding feeder protection functions. REC316*4 measures the currents and voltages at the main CTs and VTs, calculates the corresponding real power, reactive power and frequency and transfers the data to the station control level. REC316*4 is equipped with a communication interface (IBB) for twoway communication via an optical fiber link with the station control level.
1.6.2.
Main features The library of function blocks for the REC316*4 control device includes the following control, protection, measurement and logic functions: Control function: This depends on the particular application for which it is specifically created using CAP2/316 (FUPLA function plan programming language). detection and plausibility check of switchgear position signals switchgear control interlocks generation and monitoring of switchgear commands run-time monitoring detection of alarms and alarm logic
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integration of the local mimic. definite time overcurrent peak value overcurrent inverse time overcurrent directional definite time overcurrent directional inverse time overcurrent inverse time overcurrent ground fault protection definite time overvoltage peak value overvoltage power function overtemperature frequency function rate-of-change frequency function auto-reclosure synchrocheck function Breaker failure function logic delay counter flatter detection Contact bounce filter. single-phase measuring function for U, I, f, P and Q three-phase measuring function for U, I, f, P, Q and cos three-phase current plausibility three-phase voltage plausibility.
Protection functions:
Logic functions:
Measurement and monitoring functions:
The device has an integrated disturbance recorder and event recorder. The allocation of the opto-coupler inputs, the LED signals and the auxiliary relay signal outputs, the setting of the various parameters, the configuration of the scheme and the display of the events and system variables are all performed interactively by means of the menucontrolled HMI.
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REC316*4 is equipped with serial interfaces for the connection of a local HMI (PC) and for remote communication with the station control system. REC316*4 is also equipped with continuous self-monitoring and selfdiagnostic functions. Suitable testing devices (e.g. test set XS92b) are available for quantitative testing of measurement and protection functions. REC316*4 can be semi-flush or surface mounted or can be installed in an equipment rack.
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October 04
2.2.1. 2.2. 2.2.1. 2.2.2. 2.2.3. 2.2.4. 2.2.5. 2.2.6. 2.3. 2.4. 2.5. 2.6. 2.7. 2.8. 2.9. 2.9.1. 2.9.2. 2.9.3. 2.10.
DESCRIPTION OF HARDWARESummary............................................................................................2-2 Mechanical design .............................................................................2-4 Hardware versions .............................................................................2-4 Construction.......................................................................................2-4 Casing and methods of mounting ......................................................2-4 Front of the protection unit .................................................................2-4 PC connection....................................................................................2-5 Test facilities ......................................................................................2-5 Auxiliary supply unit ...........................................................................2-6 Input transformer unit.........................................................................2-6 Main processor unit............................................................................2-7 Binary I/O unit ....................................................................................2-8 Interconnection unit............................................................................2-8 Injection unit REX010 ........................................................................2-9 Injection transformer block REX011 ................................................2-13 REX011............................................................................................2-13 REX011-1, -2 ...................................................................................2-14 Figures .............................................................................................2-18 Testing without the generator ..........................................................2-27
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2.2.1.
DESCRIPTION OF HARDWARESummary The hardware of the digital protection scheme RE.316*4 comprises 4 to 8 plug-in units, a connection unit and the casing: Input transformer unit A/D converter unit Main processor unit 1 up to 4 binary I/O units or or or Type 316GW61 Type 316EA63 Type 316VC61a Type 316VC61b Type 316DB61 Type 316DB62 Type 316DB63 Type 316NG65 or Type 316ML61a Type 316ML62a
Auxiliary supply unit Connection unit
Casing and terminals for analog signals and connectors for binary signals
The A/D converter Type 316EA63 is only used in conjunction with the longitudinal differential protection and includes the optical modems for transferring the measurements to the remote station. Binary process signals are detected by the binary I/O unit and transferred to the main processor which processes them in relation to the control and protection functions for the specific project and then activates the output relays and LEDs accordingly. The analog input variables are electrically insulated from the electronic circuits by the screened windings of the transformers in the input transformer unit. The transformers also reduce the signals to a suitable level for processing by the electronic circuits. The input transformer unit provides accommodation for nine transformers. Essentially the main processor unit 316VC61a or 316VC61b comprises the main processor (80486-based), the A/D converter unit, the communication interface control system and 2 PCMCIA slots. Binary process signals, signals pre-processed by the control logic, events, analog variables, disturbance recorder files and device control settings can be transferred via the communication interface to the station control room. In the reverse direction, signals to the control logic and for switching sets of parameter settings are transferred by the station control system to the protection. RE.316*4 can be equipped with one up to four binary I/O units.
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There are two tripping relays on the units 316DB61 and 316DB62, each with two contacts and according to version either: 8 optocoupler inputs and 6 signaling relays or 4 optocoupler inputs and 10 signaling relays.
The I/O unit 316DB63 is equipped with 14 optocoupler inputs and 8 signaling relays. The 16 LEDs on the front are controlled by the 316DB6x units located in slots 1 and 2.
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2.2. 2.2.1.
Mechanical design Hardware versions RE.316*4 is available in a number of different versions, which are listed in the data sheet under 'Ordering information'.
2.2.2.
Construction The RE.316*4 is 6 U standard units high (U = 44.45 mm) and either 225 mm (Order code N1) or 271 mm wide (Order code N2). The various units are inserted into the casing from the rear (see Fig. 12.3) and then screwed to the cover plate.
2.2.3.
Casing and methods of mounting The casing is suitable for three methods of mounting. Semi-flush mounting The casing can be mounted semi-flush in a switch panel with the aid of four fixing brackets. The dimensions of the panel cut-out can be seen from the data sheet. The terminals are located at the rear. Installation in a 19" rack A mounting plate with all the appropriate cut-outs is available for fitting the protection into a 19" rack (see data sheet). The terminals are located at the rear. Surface mounting A hinged frame (see data sheet) is available for surface mounting. The terminals are located at the rear.
2.2.4.
Front of the protection unit A front view of the protection and the functions of the frontplate elements can be seen from Fig. 12.2. A reset button is located behind the frontplate which serves three purposes: resetting the tripping relays and where the are configured to latch, also the signaling relays and LEDs and deleting the distance protection display when running the control program resetting of error messages resulting from defects detected by the self-monitoring or diagnostic functions (short press) resetting the entire protection (warm start, press for at least ten seconds) following the detection of a serious defect by the selfmonitoring or diagnostic functions.
These control operations can also be executed using the local control unit on the front of the device. Should the latter fail, the reset button can be pressed using a suitable implement through the hole in the frontplate.
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2.2.5.
PC connection In order to set the various parameters, read events and measurements of system voltages and currents and also for diagnostic and maintenance purposes, a personal computer (PC) must be connected to the optical serial interface (Fig. 12.2).
2.2.6.
Test facilities A RE.316*4 protection can be tested using a test set Type XS92b.
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2.3.
Auxiliary supply unit The auxiliary supply unit 316NG65 derives all the supply voltages the protection requires from the station battery. Capacitors are provided which are capable of bridging short interruptions (max. 50 ms) of the input voltage. The auxiliary supply unit is protected against changes of polarity. In the event of loss of auxiliary supply, the auxiliary supply unit also generates all the control signals such as re-initialization and blocking signals needed by all the other units. The technical data of the auxiliary supply unit are to be found in the data sheet.
2.4.
Input transformer unit The input transformer unit 316GW61 serves as input interface between the analog primary system variables such as currents and voltages and the protection. The mounting plate of the unit can accommodate up to nine CTs and VTs. The shunts across the secondaries of the CTs are also mounted in the input transformer unit. The input transformers provide DC isolation between the primary system and the electronic circuits and also reduce (in the case of the CTs, with the aid of a shunt) the voltage and current signals to a suitable level for processing by the A/D converters. Thus the input transformer unit produces voltage signals at its outputs for both current and voltage channels. The CTs and VTs actually fitted in the input transformer unit vary according to version. Further information can be obtained from the data sheet.
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2.5.
Main processor unit The main processor runs the control and protection algorithms as determined by the particular settings. It receives its data from the A/D converter unit and the I/O unit. The results computed by the algorithms are transferred either directly or after further logical processing to the binary I/O unit. A 80486-based microprocessor is used in the main processor unit 316VC61a or 316VC61b. The samples taken by the A/D converter are pre-processed by a digital signal processor (DSP). The interfaces for connecting an HMI PC and for communication with the station control system (SPA, IEC60870-5-103) are included. A PCMCIA interface with two slots facilitates connection to other bus systems such as LON and MVB. The flash EPROMs used as program memory enable the software to be downloaded from the PC via the port on the front. A self-monitoring routine runs in the background on the main processor. The main processor itself (respectively the correct operation of the program) is monitored by a watchdog.
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2.6.
Binary I/O unit The binary I/O unit 316DB6x enables binary signals received via optocouplers from station plant to be read and tripping and other signals to be issued externally. All the input and output units provide electrical insulation between the external signaling circuits and the internal electronic circuits. The I/O units in slots 1 and 2 also control the statuses of 8 LEDs each on the frontplate via a corresponding buffer memory. The numbers of inputs and outputs required for the particular version are achieved by fitting from one to four binary I/O units. The relationship between the versions and the number of I/O units is given in the data sheet. The optocoupler inputs are adapted to suit the available input voltage range by choice of resistor soldered to soldering posts. This work is normally carried at the works as specified in the order. The technical data of the optocoupler inputs and the tripping and signaling outputs can be seen from the data sheet.
2.7.
Interconnection unit The wiring between the various units is established by the interconnecting unit 316ML62a (width 271 mm) or 316ML61a (width 225 mm). It is located inside the housing behind the frontplate and carries the connectors and wiring needed by the individual units. In addition, the interconnection unit includes the connections to the local control unit, the reset button and 16 LEDs for status signals.
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2.8.
Injection unit REX010 The injection unit Type REX010 provides the power supply for the injection transformer block Type REX011. The injection transformer block generates the signals needed for the 100% stator and rotor ground fault protection schemes. The signals all have the same waveform (see Fig. 2.3). The injection unit is installed in an REG316*4 casing and therefore the mechanical and general data are the same as specified for the REG316*4. Three versions of the injection unit with the designations U1, U2 and U3 are available for the following station battery voltages:
Battery voltage U1: 110 or 125 V DC U3: 48; 60; 110 V DC
Tolerance +10 % / -20 % 36...140 V DC
Output 110 V or 125 V, 1.1 A 96 V, 1 A 96 V, 1 A
U2: 110; 125; 220; 250 V DC 88...312 V DC
Versions U2 and U3 operate with a DC/DC converter. Newer injection units with the auxiliary supply unit 316NE62 are marked with the code U0 and have only one variant with an voltage range from 36 to 312 V. The frequency of the injection voltage, which corresponds precisely to 14 of the rated frequency of 50 Hz or 60 Hz, can be selected by positioning a plug-in jumper on PCB 316AI61. The frequency is then 12.5 Hz in position X12 and 15.0 Hz in position X11. Controls and signals: Green LED READY: Auxiliary supply switched on Red LED OVERLOAD: The internal protection circuit has picked up and injection is interrupted. Yellow LED DISABLED: Injection is disabled on the switch on the frontplate or via the optocoupler input. Toggle switch ENABLE, DISABLE: Position 0: Injection enabled. Position 1: Injection disabled. Reset button RESET: The protection circuit latches when it operates and is reset by this button upon which the red LED extinguishes.
Only the green LED is lit during normal operation.
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RE.316*4 1KHA000835-UEN
The protection circuit guards against excessive feedback from the generator and interrupts the injection for zero-crossing currents 5 A. The protection circuit will not reset, if the fault that caused it to pick up is still present. In such a case, switch off the supply and check the external wiring for short-circuits and open-circuits. Optocoupler input: This has the same function as the reset button and can also be used to disable injection. The latter occurs when the input is at logical '1'. Injection is resumed as soon as the input returns to logical '0'.
IMPORTANT: Ensure that the injection voltage is switched off before carrying out any work at the star-point. The toggle switch on the front of the injection unit REX010 must be set to 'disable' and the yellow LED 'disabled' must lit.The input voltage, the injection frequency and the optocoupler voltage must be specified in the customers order and are then set in the works prior to delivery. There are no controls inside the unit, which have to be set by the user. Supply failure If the green LED READY is not lit in the case of version U1 although the correct auxiliary supply voltage is applied, check and if necessary replace the fuse on the supply unit 316NE61. The fuse holder is located at the rear next to the auxiliary supply terminals. Fuse type: cartridge 2 A slow 5 x 20 mm
Faulty U2, U3 and U0 units must be returned to the nearest ABB agent or directly to ABB Switzerland Ltd, Baden, Switzerland.
2-10
RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
Fig. 2.1
Injection unit REX010 (front view) (corresponds to HESG 448 574)
2-11
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
Fig. 2.2
PCB 316AI61 in the injection unit (derived from HESG 324 366) showing locations of X11 and X12
2-12
RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
2.9.
Injection transformer block REX011 In conjunction with the injection unit Type REX010, the injection transformer block Type REX011 supplies the injection and reference signals for testing the 100% stator and rotor ground fault protection schemes. The injection transformer block used must correspond to the method of grounding the stator circuit: primary injection at the star-point: secondary injection at the star-point: secondary injection at the terminals: REX011 REX011-1 REX011-2
Each injection transformer type has three secondary windings for the following voltages: Uis: Uir: Ui: stator injection voltage rotor injection voltage reference voltage connected to analog input channel 8 of REG316*4.
The same injection transformer is used for stator and rotor protection schemes. The rated values of the injection voltages Uis, Uir and Ui apply for the version REX010 U1 and a station battery voltage of UBat = 110 V DC. All the voltages are less by a factor of 96/110 = 0.8727 in the case of versions U2 and U3. Thus the primary injection voltage for the stator circuit is 96 V. 2.9.1. REX011 This version is designed for primary injection at the star-point and is available with the following rated voltages:Uis Uir Ui 110 V 50 V 25 V*)
Table 2.1
REX011
*) The winding for voltage Uir has a tapping at 30 V. This enables Uir to be stepped down to 30 V or 20 V where an injection voltage less than 50 V is necessary.
2-13
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
2.9.2.
REX011-1, -2 The injection transformers have the following IDs (see Table 2.2 and Table 2.3): HESG 323 888 M11, M12 or M13 for REX011-1 HESG 323 888 M21, M22 or M23 for REX011-2
The injection transformers used for secondary injection of the stator circuit have four injection voltage windings connected in parallel or series to adjust the power to suit the particular grounding resistor. The value of the parallel resistor R'Ps, respectively the maximum injection voltage determine the permissible injection voltage.
R'Ps [m] >8 > 32 > 128
Uis [V] 0.85 1.7 3.4
Version M11 M12 M13
Table 2.2
REX011-1
R'Ps [] > 0.45 > 1.8 > 7.2
Uis [V] 6.4 12.8 25.6
Version M21 M22 M23
Table 2.3
REX011-2
Always select the maximum possible injection voltage. For example, for a grounding resistor R'Ps = 35 m, Uis = 1.7 V is used. In the case of versions M11, M12 and M13, the impedance of the connection between the injection transformer and the grounding resistor R'Ps should be as low as possible. The resistance of both connecting cables should not exceed 5% of R'Ps, e.g. for a grounding resistor of R'Ps = 35 m and a length of the connecting cables of 2 2 m = 4 m, the cables must have a gauge of 40 mm2. Voltages Uir and Ui are the same as for REX011.
2-14
RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
The connections to the primary system are made via the two UHV heavy-duty terminals 10 and 15, which are designed for spade terminals. There are four universal terminals 11 to 14 type UK35 between the two heavy-duty terminals that are used for the internal wiring. Depending on the version, the four windings must be connected to the corresponding universal or heavy current terminals. Should the version as supplied be unsuitable for the application, the connections of the windings can be modified as required according to the following diagrams. In the case of versions M12, M22, M13 and M23, shorting links KB-15 must be placed on the universal terminals. How this is done can be seen from the diagram 'Shorting links' at the end of this section. Shorting links and 3 rating plates are supplied with every transformer. The corresponding rating plate must be affixed over the old one following conversion.
Versions M11 and M21S310 11 12
S413 14
S515
S616 17
10
11
12 13
14
15
heavy-duty terminals (UHV) universal terminals (UK)
In the case of versions M11 (REX011-1) and M21 (REX011-2), the two windings S3 and S4 are connected in parallel across the heavy-duty terminals (10, 15). The other two windings are not used and are wired to the universal terminals. The shorting links KB-15 are not needed and must be removed.
2-15
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
Versions M12 and M22S310 11
S412 13
S514 15
S616 17
10
11
12
13
14
15
heavy-duty terminals (UHV) universal terminals (UK) shorting links KB-15
In the case of versions M12 (REX011-1) and M22 (REX011-2), two pairs of parallel windings are connected in series. All the universal terminals are connected together using the shorting links KB-15.
Versions M13 and M23S310 11 12
S413
S514 15
S616 17
10
11
12
13
14
15
heavy-duty terminals (UHV) universal terminals (UK) shorting links KB-15
In the case of versions M13 (REX011-1) and M23 (REX011-2), all the windings S3...S6 are connected in series. Terminals M12 and M13 are bridged by a shorting link KB-15.
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RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
In the following figure the shorting links of the versions M12 and M22 are shown:
Shorting links Terminal screws
Shorting links
Universal terminals Teminals 11 to 14
4 terminal screws, 3 shorting links with offset and 1 flat shorting link are supplied with every transformer. The shorting links are placed in the recesses provided on the universal terminals. Versions M12 and M22: First place the broken off shorting link with the opening downwards on terminal 11 and then fit 3 links one after the other. Each one must be secured using one of the screws supplied. Versions M13 and M23: First place the broken off shorting link with the opening downwards on terminal 12 and then fit 2 links one after the other. Each one must be secured using one of the screws supplied.
2-17
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
2.9.3.
Figures Fig. 2.3 Fig. 2.4 Fig. 2.5 Fig. 2.6 Fig. 2.7 Fig. 2.8 Fig. 2.9 Fig. 2.10 Fig. 2.11 Injection signal Uis Wiring diagram for primary injection at the stator using REX011 Wiring diagram for secondary injection of the stator at the star-point using REX011-1 Wiring diagram for secondary injection of the stator at the terminals using REX011-2 Wiring diagram for rotor ground fault protection using REX011 Wiring diagram for rotor ground fault protection using REX011-1, -2 Wiring diagram for testing without the generator using REX011 Wiring diagram for testing without the generator using REX011-1, -2 Dimensioned drawing of the injection transformer block Type REX011
[V]110
-110
Injection
Test
0
320
640
[ms]
Fig. 2.3
Injection signal Uis
2-18
RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
R
S
T
Generator
REG316*4T18
REX010T. T.
X1Ui1
REX011
X1 6
REs
N12
N11 Us
5
5
rest+ rest-
7 6 8 3
Voltage transformer
T17
7Ui2
RPs
3 10 Ui T15
UBat+ 3 UBat- 2
4
Ui3 Up8+ Up8-
4 1 2 P8nax
11
T16
1 2
Fig. 2.4
Wiring diagram for primary injection at the stator using REX011 (see Fig. 2.11)
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ABB Switzerland LtdR S T
RE.316*4 1KHA000835-UEN
Generator Voltage transformer N1 Grounding transformator N2 N'12 N'11 Us
REG316*4T18
R'Es R'Ps
T17
REX010T. T.
X1Ui1
REX011-1
T15 X210
5
5
rest+ rest-
7 6 8 3
Uis15Ui2
T16
3
X184
Ui3 Up8+ Up8-
4 1 2 P8nax
9
Ui
UBat+ 3 UBat2
1 2
Fig. 2.5
Wiring diagram for secondary injection of the stator at the star-point using REX011-1 (see Fig. 2.11)
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RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
R
S
T
Grounding transformator
N1
N2
Voltage transformer N'12 N'11 Us
REG316*4T18
R'Es R'PsGenerator
T17
REX010T. T.
X1Ui1
REX011-2
T15X2 10
5
5
rest+ rest-
7 6 8 3
Uis15Ui2
T16
3
X184
Ui3 Up8+ Up8-
4 1 2 P8nax
9
Ui
UBat+ 3 UBat2
1 2
Fig. 2.6
Wiring diagram for secondary injection of the stator at the terminals using REX011-2 (see Fig. 2.11)
2-21
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
+ Rotor
2x2 uF
8 kV
2x2 uF 2) 1)
8 kV
REG316*4T14
REX010T. T.
X1Ui1
REX011
RErX1 8
5
5
T13
rest+ rest-
7 6 8 3
RPr9Ui2
316 GW61
3 10 Ui
T15
UBat+ 3 UBat- 2
4
Ui3 Up8+ Up8-
4 1 2 P8nax
11
T16
1 2
1) 2)
Injection at both poles Injection at one pole for brushless excitation
Fig. 2.7
Wiring diagram for rotor ground fault protection using REX011 (see Fig. 2.11)
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RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
+ Rotor
2x2 uF
8 kV
2x2 uF 2) 1)
8 kV
REG316*4T14
REX010T. T.5
REX011-1, -2X1Ui1
REr6
X1
5
T13
rest+ rest-
7 6 8 3
RPr7Ui2
316 GW61
3 8 Ui
T15
UBat+ 3 UBat- 2
4
Ui3 Up8+ Up8-
4 1 2 P8nax
9
T16
1 2
1) Injection at both poles 2) Injection at one pole for brushless excitation
Fig. 2.8
Wiring diagram for rotor ground fault protection using REX011-1, -2 (see Fig. 2.11)
2-23
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
S1
Ck = 4 uF S2 Rf CE = 1 uF
1k 2,5 W
REG316*4T18
REX010T. T.
X1Ui1
REX011
X1 8
22
Us
5 7 6 8 3
5
T17150
50 V9Ui2
>10 WT14Ur
3
104
T13 T15Ui
Ui3 Up8+ Up8-
4 1 2 P8nax
UBat+ 3 UBat- 2
11
1 2
T16
Fig. 2.9
Wiring diagram for testing without the generator using REX011
S1: Ck: Rf: S2:
Bridging of the rotor coupling capacitor Rotor coupling capacitor Variable ground fault resistor Ground fault resistor = 0
CE: Rotor/stator ground capacitance
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RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
S1
Ck = 4 uF S2Rf
CE = 1 uF
REG316*41 k 2,5 W
REX010T. T.
REX011-1, -2X1 Ui1X1
T18
22
UsT17
5 7 6 8 3
5
6
50 V7Ui2
150 >10 W
316 GW61T13
3
Ur8
T14 T15Ui
UBat+ UBat-
3 2
4
Ui3Up8+ Up8-
4 1 2
9
1 2
P8nax
T16
Fig. 2.10
Wiring diagram for testing without the generator using REX011-1, -2
S1: Ck: Rf: S2:
Bridging of the rotor coupling capacitor Rotor coupling capacitor Variable ground fault resistor Ground fault resistor = 0 .
CE: Rotor/stator ground capacitance
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ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
Fig. 2.11
Dimensioned drawing of the injection transformer block Type REX011 (corresponds to HESG 324 388)
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RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
2.10.
Testing without the generator
In order to test the operation of the injection unit Type REX010 plus injection transformer block Type REX011 or REX011-1/-2 and the Stator-EFP and Rotor-EFP protection functions without them being connected to the protected unit, set up the test circuit shown in Fig. 2.9 or Fig. 2.10.The two grounding resistors RE and RP are used for both stator and rotor protection schemes to simplify the circuit. The injection voltage of 50 V is also common to both. The ground fault resistance is simulated by the variable resistor Rf.Stator ground fault protection:
To test the stator ground fault protection, switch S1 must be kept closed all the time. The grounding resistor RE comprises two resistors of 1 k and 22 . This is a simple method of simulating the ratio of the VT. Settings for MTR and REs: The theoretical value of MTR is determined as follows:
MTR =
110 V 22 + 1000 x = 102 50 V 22
The low injection voltage of 50 V increases the value of MTR by a factor 110 V/50 V. REs = 1022 The settings can also be determined using the setting functions 'MTR-Adjust' and 'REs-Adjust' according to Section 3.5.32. which is to be preferred to the above calculation.Rotor ground fault protection:
To test the rotor ground fault protection, the switch S1 must be kept open all the time with the exception of when the coupling capacitor is bridged for setting mode 'AdjRErInp'. Settings: The theoretical settings are: REr = 1022 Ck = 4 F The settings can also be determined using the setting functions 'REsAdjust' and 'CoupC-Adjust' according to Section 3.5.33. which is to be preferred to the above calculation.
2-27
RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
October 2004
3.3.1. 3.1.1. 3.1.2. 3.1.2.1. 3.1.2.2. 3.1.2.3. 3.2. 3.2.1. 3.2.2. 3.2.3. 3.2.4. 3.2.5. 3.3. 3.4. 3.4.1. 3.4.2. 3.4.3. 3.4.4. 3.4.5. 3.5. 3.5.1. 3.5.2. 3.5.2.1. 3.5.2.2. 3.5.2.2.1. 3.5.2.2.2. 3.5.2.2.3. 3.5.2.2.4. 3.5.2.2.5. 3.5.2.2.6. 3.5.2.3. 3.5.2.3.1. 3.5.2.3.2. 3.5.2.3.3. 3.5.2.3.4. 3.5.2.3.5. 3.5.2.4. 3.5.2.5. 3.5.2.6. 3.5.2.7. 3.5.2.8.
SETTING THE FUNCTION PARAMETERSGeneral ..............................................................................................3-5 Library and settings............................................................................3-5 Control and protection function sequence .........................................3-5 Repetition rate....................................................................................3-5 Computation requirement of protection functions ..............................3-6 Computing requirement of the control functions ..............................3-10 Control and protection function inputs and outputs..........................3-10 Analog / Digital Converter ................................................................3-10 Binary inputs ....................................................................................3-11 Signalling outputs.............................................................................3-11 Tripping relay outputs ......................................................................3-12 Measured variables..........................................................................3-12 Frequency range..............................................................................3-13 System parameter settings ..............................................................3-13 Relay configuration ..........................................................................3-13 Configuration of the A / D Converter................................................3-16 Entering comments for binary inputs and outputs............................3-18 Masking binary inputs, entering latching parameters and definition of 'double indications' .......................................................3-18 System I / O .....................................................................................3-19 Protection functions .........................................................................3-23 HV distance protection function .......................... (HV-Distance)......3-23 Distance protection ................................................... (Distance)......3-25 General ............................................................................................3-47 Starters ............................................................................................3-48 Overcurrent starters .........................................................................3-48 Underimpedance starters.................................................................3-48 Current enable .................................................................................3-50 E/F detector .....................................................................................3-51 Phase preference logic ....................................................................3-51 Undervoltage starters.......................................................................3-52 Measuring units................................................................................3-52 Determining the distance zones.......................................................3-52 Directional element ..........................................................................3-58 Overreaching zone...........................................................................3-59 Reverse zone...................................................................................3-59 Time steps .......................................................................................3-59 Definitive zone .................................................................................3-60 Back-up overcurrent protection........................................................3-61 VT supervision .................................................................................3-62 Tripping logic....................................................................................3-63 Power-swing blocking ......................................................................3-653-1
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
3.5.2.9. 3.5.2.10. 3.5.2.11. 3.5.2.12. 3.5.3. 3.5.4. 3.5.4.1. 3.5.4.2. 3.5.4.3. 3.5.4.4. 3.5.4.5. 3.5.4.6. 3.5.4.7. 3.5.4.8. 3.5.4.9. 3.5.4.10. 3.5.4.11. 3.5.5. 3.5.5.1. 3.5.5.2. 3.5.5.3. 3.5.5.4. 3.5.5.5. 3.5.5.6. 3.5.5.7. 3.5.5.8. 3.5.5.9. 3.5.5.10. 3.5.5.11. 3.5.5.12. 3.5.5.13. 3.5.6. 3.5.7. 3.5.8. 3.5.9. 3.5.10. 3.5.11. 3.5.12. 3.5.13. 3.5.14. 3.5.15.
Allocation of CT and VT inputs ........................................................3-65 Allocation of binary inputs ................................................................3-65 Allocation of tripping commands ......................................................3-67 Signals .............................................................................................3-67 Sensitive earth fault protection for ungrounded systems and systems with Petersen coils......... (EarthFaultIsol)......3-69 Auto-reclosure................................................... (Autoreclosure)......3-75 General ............................................................................................3-90 Connections between auto-reclosure and distance functions ............................................................................3-90 Connections between auto-reclosure and overcurrent or differential functions..................................................3-92 Redundant schemes ........................................................................3-94 Master/follower logic ........................................................................3-96 Duplex logic .....................................................................................3-98 Timers ............................................................................................3-100 External binary inputs ....................................................................3-103 Close CB and signalling outputs ....................................................3-105 Timing diagrams ............................................................................3-107 Checking the dead times ...............................................................3-117 Sensitive earth fault protection for grounded systems..............................................(EarthFltGnd2)....3-119 Coordination with the distance protection ......................................3-125 Choice of operating mode..............................................................3-126 Choice of transfer tripping scheme ................................................3-126 Setting the enabling pick-up levels ................................................3-130 Setting the characteristic angle 'Angle' ..........................................3-131 Setting the basic time 't Basic' .......................................................3-131 Circuit-breaker delay......................................................................3-132 The comparison time 't comp' ........................................................3-132 Setting the waiting time 't Wait' ......................................................3-132 Setting the transient blocking time 't TransBlk' ..............................3-132 CT/VT inputs of the function ..........................................................3-133 Binary inputs of the function...........................................................3-133 Outputs ..........................................................................................3-134 Inverse definite minimum time earth fault overcurrent function .................................................. (I0-Invers)....3-135 Definite time over and undercurrent...................... (Current-DT)....3-141 Peak value overcurrent ........................................ (Current-Inst)....3-147 Inverse time overcurrent ....................................... (Current-Inv)....3-153 Directional definite time overcurrent protection ...........................................................(DirCurrentDT)....3-159 Directional inverse time overcurrent protection ...........................................................(DirCurrentInv)....3-167 Definite time NPS.......................................................(NPS-DT)....3-179 Inverse time NPS .......................................................(NPS-Inv)....3-183 Voltage-controlled overcurrent...............................(Imax-Umin)....3-187 Definite time over and undervoltage protection .............................................................. (Voltage-DT)....3-1953-2
RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
3.5.15.1. 3.5.15.2. 3.5.15.3. 3.5.16. 3.5.17. 3.5.18. 3.5.19. 3.5.19.1. 3.5.19.2. 3.5.19.3. 3.5.20. 3.5.21. 3.5.22. 3.5.23. 3.5.24. 3.5.25. 3.5.26. 3.5.27. 3.5.28. 3.5.29. 3.5.30. 3.5.31. 3.5.32. 3.5.33. 3.5.34. 3.6. 3.6.1. 3.6.1.1. 3.6.1.1.1. 3.6.1.1.2. 3.6.1.1.3. 3.6.1.1.4. 3.6.1.1.5. 3.6.1.1.6. 3.6.1.1.7. 3.6.1.2. 3.6.2. 3.6.3. 3.6.4. 3.6.5. 3.6.6. 3.6.7. 3.7. 3.7.1. 3.7.2. 3.7.3. 3.7.4. 3.7.5.
Definite time stator earth fault (95 %) ............................................3-200 Rotor E/F protection.......................................................................3-210 Interturn protection.........................................................................3-212 Peak value overvoltage........................................ (Voltage-Inst)....3-213 Power............................................................................(Power)....3-217 Overtemperature protection ................................... (Overtemp.)....3-231 Synchrocheck function.......................................(SynchroChck)....3-239 General ..........................................................................................3-247 Settings ..........................................................................................3-249 Binary inputs of the function...........................................................3-255 Breaker failure protection................................ (BreakerFailure)....3-259 Transformer differential protection function ........... (Diff-Transf)....3-273 Generator differential .................................................(Diff-Gen)....3-297 Frequency protection ............................................. (Frequency)....3-303 Rate-of-change of frequency protection........................... (df/dt)....3-307 Overfluxing............................................................ (Overexcitat)....3-311 Inverse time overfluxing ............................................... (U/f-Inv)....3-315 Balanced voltage ................................................. (Voltage-Bal)....3-323 Underimpedance................................................. (Underimped)....3-329 Loss Of Excitation ............................................ (MinReactance)....3-337 Stator overload.................................................. (OLoad-Stator)....3-349 Rotor overload ................................................... (OLoad-Rotor)....3-355 Stator ground fault ................................................ (Stator-EFP)....3-361 Rotor Ground Fault (Injection Principle) protection ............................................................... (Rotor-EFP)....3-383 Pole slipping..............................................................(Pole-Slip)....3-393 Control functions ............................................................................3-405 Control function........................................................... (FUPLA)....3-405 Control function settings - FUPLA..................................................3-407 General ..........................................................................................3-408 Timers ............................................................................................3-409 Binary inputs ..................................................................................3-409 Binary signals.................................................................................3-409 Measurement inputs ......................................................................3-410 Measurement outputs ....................................................................3-410 Flow chart for measurement inputs and outputs............................3-410 Loading FUPLA..............................................................................3-410 Logic .............................................................................. (Logic)....3-411 Delay / integrator............................................................(Delay)....3-415 Counter ...................................................................... (Counter)....3-419 Contact bounce filter ...............................................(Debounce)....3-421 Signal flutter detector ............................................(Defluttering)....3-423 LDU events ........................................................... (LDUevents)....3-427 Measurement functions..................................................................3-429 Measurement function .................................................. (UIfPQ)....3-429 Three-phase current plausibility............................(Check-I3ph)....3-433 Three-phase voltage plausibility ......................... (Check-U3ph)....3-437 Disturbance recorder ................................... (Disturbance Rec)....3-441 Measurement module .......................... (Measurement Module)....3-4553-3
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
3.7.5.1. 3.7.5.2. 3.7.5.3. 3.7.5.4. 3.8. 3.8.1. 3.8.1.1. 3.8.1.2. 3.8.1.3. 3.8.1.4. 3.8.2. 3.8.2.1. 3.8.2.2. 3.8.3.
Impulse counter inputs...................................................................3-461 Impulse counter operation .............................................................3-462 Impulse counter operating principle ...............................................3-462 Interval processing.........................................................................3-463 Data transmission ..........................................................................3-465 Principle of operation of the A/D converter 316EA63 ....................3-465 Introduction ....................................................................................3-465 Synchronisation principle ...............................................................3-465 Data transmission principle............................................................3-465 Consequences of transmission errors ...........................................3-465 Longitudinal differential protection .............................(Diff-Line)....3-467 Setting instructions for lines with a power transformer in the protected zone ....................................3-473 Setting instructions for lines without a power transformer in the protected zone ....................................3-483 Binary data transmission....................................... (RemoteBin)....3-489
3-4
RE.316*4 1KHA000835-UEN
ABB Switzerland Ltd
3.3.1. 3.1.1.
SETTING THE FUNCTION PARAMETERSGeneral Library and settings RE.316*4 provides a comprehensive library of protection and control functions for the complete protection of lines, feeders, transformers, and generators. The setting procedure is carried out with the aid of a personal computer and is extremely user-friendly. The number of protection and control functions active in a RE.316*4 system is limited by the available computing capacity of the processing unit. In each case, the control program checks whether sufficient computing capacity is available otherwise an error message is displayed. The maximum number of protection functions is 48. The settings and the software key determine which functions are active. This facilitates configuration of different protection scheme: Only functions that are actually needed should be activated. Every active function entails computing effort, which can influence the operating time. Many of the functions can be used for multiple purposes, e.g.: to achieve several stages of operation (with the same or different settings and time delays) for use with different input channels.
Other functions can only be configured for one specific purpose in each set of parameter settings: binary signal transmission disturbance recorder contact bounce filter (Debounce) IEC 60870-5-103.
Functions active in the same set of settings can be logically interconnected, e.g. for interlocking purposes.
3.1.2. 3.1.2.1.
Control and protection function sequence Repetition rate The protection system software controls the operating sequence of the individual functions. The latter are divided into routines, which are processed cyclically by the microprocessor. The frequency of the processing cycle (repetition rate) is determined by the technical requirements of the application.
3-5
ABB Switzerland Ltd
RE.316*4 1KHA000835-UEN
For many functions, this depends on the permissible or desired tripping delay. From this follows that the faster tripping should take place, the higher will be the repetition rate. Typical relationships between tripping delay and repetition rate can be seen from Table 3.1.Repetition rate 4 2 11) for 50 Hz or 60 Hz
Explanation 4 times every 20 ms 1) 2 times every 20 ms 1 time every 20 ms
Delay time < 40 ms 40 ... 199 ms 200 ms
Table 3.1
Typical protection function repetition rates
The repetition rates of some of the functions do not depend on their settings, e.g. the distance protection always has a repetition rate of 4 and the auto-reclosure 1. The scanning of the binary inputs and the setting of the signalling and tripping outputs takes place at the sampling rate of the analog inputs. While the operating speed of the various protection functions is more than adequate for their purpose, they do operate in sequence so that the effective operating times of output signals such as 'Start' and 'Trip' are subject to some variation. This variation is determined by the repetition rate controlling the operation of the function. Typical values are given in Table 3.2.Repetition rate 4 2 1 Variation -2...+5 ms -2...+10 ms -2...+20 ms
Table 3.2
Variation in the operating time of output signals of protection functions in relation to their repetition rates
3.1.2.2.
Computation requirement of protection functions The amount of computation a function entails is determined by the following factors: complexity of the algorithms used. This is characteristic for each protection function. Repetition rate: The faster the operating time of a protection function, the higher its repetition rate according to Table 3.1. The computation requirement increases approximately in proportion to the repetition rate.
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Already active protection functions: The protection system is able to use certain intermediate results (measured variables) determined by a protection function several times. In consequence, additional stages of the same protection function with the same inputs generally only involve a little more computation for the comparison with the pick-up value, but not for conditioning the input signal.
The computation requirement of the RE.316*4 protection functions can be seen from Table 3.3. The values given are typical percentages in relation to the computing capacity of a fictitious main processing unit. According to Table 3.1, the computation requirement of some of the functions increases for low settings of the time delay t and therefore a factor of 2 or 4 has to be used in some instances. When entering the settings for a function with several stages, the one with the shortest time delay is assumed to be the first stage. The computing performance of a RE.316*4 is 250 %, providing a 316VC61a or 316VC61b central processor is fitted. This applies to all devices equipped with the local control unit on the front. The computing performance of older devices with a 316VC61 central processing unit is limited to 200 %. The computing load can be viewed by selecting 'List Procedure List' from the 'List Edit Parameters' menu and is given for the four sets of parameters in per thousand.
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Function 1ph Distance (min.) starters Z< Meas Bward VTSupNPS Power Swing HV distance (min) Meas Bward VTSupNPS Power Swing EarthFltIsol Autoreclosure EarthFltGnd2 I0-Inverse Current-DT with Inrush Blocking Current-Inst Current-Inv DirCurrentDT DirCurrentInv NPS-DT NPS-Inv Imax-Umin Voltage-DT Voltage-Inst Voltage-Bal Underimped MinReactance Oload-Stator Oload-Rotor Power Overtemp. Frequency df/dt Overexcitat U/f-inv Stator-EFP Rotor-EFP Pole-Slip Diff-Gen Diff-Transf SynchroCheck Diff-Line RemoteBin SS-Umschalt BreakerFailure FUPLA 34 ----5 2 3 4 6 6 4 -5 12 15 50 15 25,5 3 4 2
1st stage 3ph 50 20 5 3 15 70 5 3 15 5 1 10 4 3 5 4 7 19 21 6 8 8 3 4 9 17 17 7 6 14 15 --
2nd and higher stages 1ph 3ph
Factor t < 40 ms
(**) t < 200 ms
ditto ditto ditto 3 1 5 2 3 ditto ditto 1 3 2 1 2 ditto 4 4 3 3 3 ditto 3 5 --ditto ditto ditto ditto ditto 40 50 ditto ditto ditto ditto (*) ditto 46 ditto ditto 8 11 11
4
2
4
2
4 4 4
2 2 2
4
2
4 4 4 4
2 2 2 2
2
2
2
40 40 20
16 50 8 30
2
1/2/4 (***)
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Function 1ph IEC60870-5-103 Logic Delay Counter Debounce Defluttering Analog RIO Trig LDU events UifPQ MeasureModule Voltage/CurrentInp Cnt Check-I3ph Check-U3ph DisturbanceRec without binary I/P with binary I/P (*) can only be set once
1st stage 3ph 1 4 8 8 0.1 4 2 4 5
2nd and higher stages 1ph (*) ditto ditto ditto (*) ditto ditto ditto ditto 3ph
Factor t < 40 ms
(**) t < 200 ms
4
2
10 8 5 5
ditto ditto ditto ditto
20 40
(*) (*)
(**) always 1 for delays 200 ms
(***) depends on repetition rate (low / medium / high)
Table 3.3
Computation requirement of protection functions (in percent)
Example: Table 3.4 shows the computation requirement according to Table 3.3 of a simple protection scheme with four active functions. Since functions 1 and 2 use the same analog inputs, the amount of computing capacity required for function 2 is reduced to that of a second stage.
Function No. 1 2 3 4 Total Type Current-DT Current-DT Current-DT Voltage-DT
Input channel 1 (,2,3) 1 (,2,3) 4 7 Phases three three single single
Settings Pick-up 10.0 IN 2.5 IN 3.5 IN 2.0 UN Time 30 ms 100 ms 300 ms 50 ms
Percentage incl. factor 3% 4 = 12% 1% 2 = 2% 2% 1 = 2% 2% 2 = 4% 20%
Table 3.4
Example for calculating the computation requirement
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3.1.2.3.
Computing requirement of the control functions The computing requirement of the control functions cannot be directly represented as a percent of the total computing capacity. The size of the code, the type of control logic also determines the computing requirement. The protection and control function load on the main processor can be checked after loading the program by selecting 'Display AD Channels' from the 'Monitor' menu and checking the value of the 'Loop time'.
Fig. 3.1
Display of the computing time
The 'Loop time' is a measure of the computing requirement. When all the functions are active, i.e. none are disabled, this number must not exceed 20000. The value must be read when the device is in the normal operating state and not during a trip. Set the cycling time of the high-priority task to 20 ms (default, see Section 3.6.1.1. 'Control function settings - FUPLA'). This ensures the correct processing of the protection and control functions.
3.2. 3.2.1.
Control and protection function inputs and outputs Analog / Digital Converter(see Section 5.4.2.6.)
The protection scheme can include three types of input transformers, which can also have different ratings: protection CTs metering CTs (core-balance) VTs.
The number and arrangement of the input transformers are defined either by sub-code K.. in the ordering code or by transformer type entered for K=0. Before being processed by the protection functions, the currents and voltages coming from the input transformers are digitised in the analog section of the main processor unit. Every analog input channel is designated either single or three-phase: CTs: three-phase protection single-phase protection single-phase metering (core-balance)
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VTs: three-phase Y connected 3-phase, delta connection single-phase
A protection function can only be used in a three-phase mode, if a corresponding three-phase group of CT/VT input channels is available. All protection function settings are based on the input values (secondary ratings) of the RE.316*4. The fine adjustment to suit the effective primary system quantities is accomplished by varying the reference settings of the analog inputs.
3.2.2.
Binary inputs(see Section 5.4.2.1.)
RE.316*4 recognises one of the following values: logical '0' (fixed value) or FALSE logical '1' (fixed value) or TRUE binary input value (316DB6.) binary control and protection values as defined by the function number and the corresponding signalling output binary values from the station control level binary values from the distributed input units (500RIO11) binary values with interlocking data.
All the above can also be set as binary inputs of control and protection functions. All the binary addresses set may be used either directly or inverted.
3.2.3.
Signalling outputs(see Section 5.4.2.3.)
All the control and protection signalling outputs provide the following facilities: external signalling via LEDs external signalling via relays event recording control of tripping relays external signalling via the communications interface external signalling via distributed output units (500RIO11) output of interlocking data.
The following applies to external signals via a signalling relay or a LED: A signalling relay or LED can only be activated by a one signal. Every signalling relay and LED can be individually set to latch.
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A signal can activate up to two output channels, e.g.: 2 signalling relays 1 signalling relay and 1 LED 1 signalling relay and 1 tripping relay
An output each can also be configured for the communication interface, the distributed output units, interlocking data and event recording. Important signals are duplicated, e.g. 'General Trip' and 'General Trip Aux'. 3.2.4. Tripping relay outputs(see Section 5.4.2.4.)
All protection functions can directly actuate the tripping relays. A tripping logic matrix is provided for this purpose, which enables any function to be connected to any tripping channel. A tripping channel can be activated by any number of protection functions. Only the binary I/O units 316DB61 and 316DB62 are equipped with tripping relays. Each unit has two relays each with two contacts for a total of four contacts. 3.2.5. Measured variables(see Section 5.5.2.)
Apart from being processed internally, the analog variables measured by the RE.316*4 protection functions can also be viewed externally as: a value: The input variables measured by the protection functions are available to the station control system via the communication interface. They can also be viewed locally on a PC (personal computer) running the operator program or on the local display unit (LDU) on the frontplate. Their values are referred to the secondary voltages and currents at the input of the RE.316*4. a recorded event: The instant a protection function trips, the value of the corresponding measured variable is recorded as an event.
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3.3.
Frequency range The protection functions can be set to operate at a power system frequency fN of either 50 Hz or 60 Hz. The algorithms, which execute the protection functions, have been optimised to produce the best results at the rated frequency fN. Discrepancies from the rated frequency cause an additional error.
3.4. 3.4.1.
System parameter settings Relay configuration Summary of parameters:Unit Nominal Frequency A/D Converter Slot Nr. 1 Slot Nr. 2 Slot Nr. 3 Slot Nr. 4 AD Config K SWVers SX... SWVers S.XXX Hz Default 50 on VC61 not used not used not used not used 0 X 100 Min. 50 (Select) (Select) (Select) (Select) (Select) 0 (Select) 1 999 1 999 1 Max. 60 Step 10
Significance of the parameters: Nominal Frequency Determination of the rated frequency: 50 Hz or 60 Hz. A/D Converter defines the type of A/D converter: on VC61: A/D converter on 316VC61a resp. 316VC61b EA62 : Line differential protection with the older A/D converter 316EA62 EA63 : Line differential protection with the newer A/D converter 316EA63 EA6. Master .: Master device EA6. Slave .: Slave device EA6. Master Fox .: Master device for data transmission via FOX EA6. Slave Fox .: Slave device for data transmission via FOX EA6. ..... S: Short data transmission distance EA6. ..... L: Long data transmission distance
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The setting of the data transmission distance is normally determined by the attenuation of the optical fibre cable between the two units. However, when using FOX optical fibre equipment, the setting is determined by the connection between the RE.316*4 and the FOX equipment. The data transmission distance setting influences the output power of the transmission diode. It must therefore be selected such that the receiver diode at the remote end is not overloaded. To make sure that the setting is correct, measure the optical signal strength while commissioning the system. The output power must be in the respective range given in the following table (MM = Multi-mode optical cable 50/125m, SM = Single-mode optical cable 9/125 m):Setting OFL Type MM SM EA6..S -26 -20 dBm -32 -22 dBm EA6..L -16 -13 dBm -20 -17 dBm
Select the setting such that taking the attenuation to be expected due to the optical cable into account, the power at the receiving end is between 34dBm to 22dBm. Measure the signal strength at the receiving end to make sure that it is within this range. Instead of measuring the optical power at the receiving end one can check the value of the received power in the diagnosis menu ( see Section 6.6). The value should be between 400 ... 15000. The transmission functions reliably outside this range, as long as no modem errors are reported. In spite of this in order to have a reserve against aging of the components (Optical cable, Transmit and Receive diodes), after the commissioning the received power should be in the range of 400 ... 15000
NOTICE: Take care when measuring the output power to set the level for the correct type of optical cable in use. One device must be configured as master (or 'EA6. Master Fox .') and the other as slave (or ' EA6. Slave Fox .'). If an A/D converter Type 316EA62 is installed, the 'A/D Converter' parameter must be set to 'EA62' even if the optical fibre link is not in operation yet.
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AD Config K: Version and type of input transformer unit: 0 ... 999: K0: A/D converter freely selectable K1 ... K9: Standard variant for REL316*4 without longitudinal distance protection K15 ... K17: Standard variant for REL316*4 with longitudinal distance protection K21 ... K24: Standard variant for RET316*4 K41 ... K47: Standard variant for REC316*4 K61 ... K67: Standard variant for REG316*4 K80 ... K999: Project specific A/D converter unit, A/D converter freely selectable A list of input transformer unit codes is to be found in the data sheet (Section 8).
NOTICE: This parameter must be set before configuring the protection functions and cannot be changed subsequently. The setting must agree with the type of the I/P transformer actually installed in the device. The hardware is not checked.Slot Nr. 1: Defines the type of I/O board in slot 1: not used, 316DB61, 316DB62 or 316DB63. Slot Nr. 2: Defines the type of I/O board in slot 2: not used, 316DB61, 316DB62 or 316DB63. Slot Nr. 3: Defines the type of I/O board in slot 3: not used, 316DB61, 316DB62 or 316DB63. Slot Nr. 4: Defines the type of I/O board in slot 4: not used, 316DB61, 316DB62 or 316DB63. SWVers SX...: First part (letter) of the software code. SWVers S.XXX: Second part (figures) of the software code. A summary of the protection functions according to software codes is given in the data sheet (Section 8).
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3.4.2.
Configuration of the A / D Converter(see Section 5.4.2.6.)
Channel type If for the hardware configuration K is set to 0 or 80999, CT and VT channels can be entered in any order, providing a corresponding input transformer unit is fitted. The codes K80 upto K999 are project specific, and are documented in the respective project schematics. In the following tables the configuration possibilities and their significance are explained. Some types of A/D converters are only utilized for specific devices.Channel Type Not used UT 1ph 0.57 IT 1ph ITM 1ph UT 1ph 1.00 UT 1ph 0.15 Description of the A/D converter channels To be selected, in case no A/D converter is used in this channel. VT 1-phase. Range 0 ... 1.3 UN Protection CT 1-phase Metering CT 1-phase VT 1-phase. Range 0 ... 2.2 UN VT 1-phase with UN = 15 V. Used for the Stator- and Rotor-ESS (for REX010/011) (Ui, Ustator). VT 3-phase in Star connection. Measurement of the phase earth voltage. Range 0 ... 1.3 UN VT 3 phase in Star connection. Measurement of the phase earth voltage. Range 0 ... 2.2 UN Protection CT 3-phase Metering CT 3-phase VT 3-phase in Delta connection. Measurement of the phase-to-phase voltage. Range 0 ... 1.3 UN VT 3-phase in Delta connection. Measurement of the phase-to-phase voltage. Range 0 ... 2.2 UN Device type ALL REL316*4 REC316*4 ALL ALL RET316*4 REG316*4 REG316*4
UTS 3ph 0.57
REL316*4 REC316*4 RET316*4 REG316*4 ALL ALL REL316*4 REC316*4 RET316*4 REG316*4
UTS 3ph 1.00
IT 3ph ITM 3ph UTD 3ph 0.57
UTD 3ph 1.00
Table 3.5
Configuration options and significance for channel type, device type and description of the A/D converters
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Nominal value Enter the rated values for the CTs and VTs in the input transformer unit (1 A, 2 A, 5 A, 100 V or 200 V). S and T phases of three-phase channels assume the same value as R phase. In order that the resolution of the impedance setting for a rated current of 5 A is meaningful, the impedance setting range for 5 A is automatically reduced by a factor of 10.
NOTICE: The ratings must be set at the beginning and not changed afterwards. This applies especially in the case of the distance function.Setting instructions for the longitudinal differential protection: The rated current settings of the channels in the remote station (channels 7, 8 and 9) must agree with the effective rated currents of the CTs in the remote station. Edit A/D prim/sec ratio This setting is utilised to correctly display the primary value in the measurands display of the HMI and LDU, for the evaluation of the disturbance records, and for the IEC60870-5-103-Protocol. S and T phases of three-phase CT and VT channels assume the same value as R phase. Edit A/D channel ref. value The reference values of the CT and VT channels enable the device ratings to by matched to those of the protected unit. They are a factor that can be set in the range 0.5 to 2. S and T phases of three-phase channels assume the same value as R phase. Example: Rated voltage = 110 V Reference value of the voltage channel =
110 V = 1.100 100 V
Effects of changing the reference values: With the exception of the impedance settings for the distance function, the protection function settings (parameters expressed in relation to 'IN' and 'UN') are automatically adjusted to the new reference values. In the case of the distance function, however, adjusting just the currents and not the voltages will change the impedance pick-up values. For this reason the reference values for the current inputs should not be changed.Edit A/D channel comment
Facility is provided for the user to enter a comment for each analog channel, which is displayed together with the channel type when the corresponding CT or VT input parameter of a protection function is selected.3-17
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3.4.3.
Ent
