Reb5_E

1MRB520259-UenEdition June 2000

Numerical Busbar andBreaker Failure ProtectionType REB 500 (BU02)

Operating Instructions

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2000 ABB Power Automation Ltd Baden/Switzerland

1st Edition

Applies for software version V5.0

All rights with respect to this document, including applications for patent andregistration of other industrial property rights, are reserved. Unauthorised use, inparticular reproduction or making available to third parties, is prohibited.

This document has been carefully prepared and reviewed. Should in spite of thisthe 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 awarranty of performance or characteristic. It is with the best interest of ourcustomers in mind that we constantly strive to improve our products and keepthem abreast of advances in technology. This may, however, lead to discrep-ancies between a product and its "Technical Description" or "Operating Instructions".

Version 5.0

1. Introduction A

2. Safety instructions A

3. Structure, function and technical specification A

4. External operator program (REBWIN) A

5. Configuration and settings A

6. Errection and installation A

7. Commissioning A

8. Operation and maintenance A

9. Fault-finding A

10. Storage, decommissioning and disposal A

11. Options A

12. Glossary A

REB 500 1MRB520259-Uen / Rev. A ABB Power Automation Ltd

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June 2000

1. INTRODUCTION

1.1. REB500....................................................................................1-2

1.2. Application................................................................................1-2

1.3. Main features ...........................................................................1-3

1.4. Options.....................................................................................1-4

1.5. Using these operating instructions ...........................................1-4

ABB Power Automation Ltd REB 500 1MRB520529-Uen / Rev. A

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1. INTRODUCTION

1.1. REB500

The digital busbar protection REB 500 belongs to the generationof fully digital protection devices, i.e. the analogue-to-digital con-version of the input variables takes place immediately after theinput transformers and all further processing of the resultingdigital signals is performed by programmable microprocessors.Its development was based on the established analogue elec-tronic busbar protection schemes INX 2 and INX 5.

The main features which enable the REB 500 to fully satisfy thedemands placed on a modern protective device with respect tocost-effectiveness and functionality are compact design, only afew different types of hardware units, modular software and con-tinuous self-supervision and diagnosis.

The structure of the protection system is bay-oriented. The bayunits may be located close to the switchgear in control and pro-tection cubicles or in a central relay room. Distributed bay unitsare connected to the central unit by an optical fibre process bus.The central unit collects all the data and executes the protectionalgorithms and auxiliary functions at station level.

1.2. Application

The digital busbar protection REB500 has been designed for thehigh-speed selective protection of MV, HV and EHV busbars in50 and 60 Hz power systems. Because of the flexible andmodular structure of both hardware and software, the protectioncan be simply configured to suit the particular busbar arrange-ment.

It is thus able to protect all busbar layouts, whether a single setof busbars or quadruple busbars with a transfer busbar. It issimilarly applicable to ring busbars and 1½ breaker schemes.The maximum capacity for a quadruple busbar system is 59feeders (59 bay units) with a maximum of 7 longitudinal break-ers, 8 sections of busbars and 32 protection zones.

The protection detects phase and ground faults in solidlygrounded and impedance grounded power systems. As with theINX 2 and INX 5 busbar protection schemes, the digital REB500scheme only evaluates the primary system currents. The mainc.t’s do not have to fulfil any special requirements as is the case,


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for example, with a high-impedance scheme. Even in the eventof saturation of the main c.t’s, the protection is still able to dis-criminate correctly between internal and external faults.

1.3. Main features

• Higher reliability due to the evaluation of two independentcriteria:- differential current with restraint feature- directional current comparison

• Independent evaluation of each phase

• Minimum c.t. performance requirements

• High through-fault stability even when c.t’s saturate

• Solid-state busbar replica

• No switching of c.t. circuits

• A single version for rated currents of 1A and 5A

• A single version for auxiliary supply voltages between 48 and250 V

• Short operating time irrespective of station size and configu-ration

• Centralised system: Hardware accommodated in one or sev-eral cubicles

• Distributed system: Bay units located close to the switchgearwith short connections to c.t’s, isolators, circuit-breakers etc.

• Signals transferred between bay units and central unit in bothcentralised and distributed schemes via optical fibre cables(max. distance approx. 1200 m)

• Optical fibre communication is immune to electrical interfer-ence even in the immediate vicinity of HV cables

• Unrestricted replacement of existing busbar protectionschemes (centralised system). Combined centralised anddistributed systems are possible when adding feeders etc.

• Simple addition of new feeders

• User-friendly human/machine interface (HMI)

• Fully digital signal processing

• Comprehensive self-monitoring

• Integrated event recorder

• Integrated disturbance recorder for power system currents

ABB Power Automation Ltd REB 500 1MRB520529-Uen / Rev. A

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• Reduced stocks of spares due to modular design and onlyfew different units

1.4. Options

• Breaker failure protection

• End zone fault protection

• Time-overcurrent protection

• Disturbance recorder for power system currents

• Separate I0 measurement for impedance grounded systems

• Communication with station control and supervision systems(LON/IEC)

• Internal user-friendly human/machine interface (HMI) withdisplay on the bay units

• Redundant power supplies for central and/or bay units

• Overcurrent check feature for tripping commands

• Low-voltage check feature for tripping commands

1.5. Using these operating instructions

The structure of these Operating Instructions is as follows:

The introduction in Section 1 is followed by safety instructionsand the significance of the corresponding symbols in Section 2.

Sections 3 to 10 explain the basic functions and the operatingprinciple of the REB500 busbar protection. Optional functionsare dealt with in Section 11.

Section 3 contains a detailed description of the hardware andsoftware design, the functions, the blocking signals, other sig-nals and the technical data.

Section 4 describes the REBWIN operator program which pro-vides facility for:

• controlling and setting REB500 using a PC

• querying system status (isolator and circuit-breaker positionsetc.)

• viewing and changing settings

• assignment of inputs and outputs

• viewing measured variables, event list etc.


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Section 5 explains the procedure for configuring the signals andcalculating the pick-up values. Should it become necessary tochange any settings, it is advisable to read this section carefully.

Section 6 contains instructions for transporting, storing and in-stalling REB500 and should be read before commencing instal-lation work.

The conditions that have to be fulfilled before commissioningREB500 and the commissioning procedure are to be found inSection 7.

Most functions of REB500 are continuously supervised, but nev-ertheless, some maintenance is necessary. The checks thatshould be made periodically are explained in Section 8.

Consult Section 9 in the event of any error messages which aredisplayed in normal operation, while starting the system or whenworking with REBWIN.

The precautions to be taken when decommissioning REB500are given in Section 10.

IMPORTANT: Optional functions are explained in Section 11.Reference is made to this section in Sections 3 to 7. Virtually allthe information on options is to be found in Section 11.

The meanings of special terms and abbreviations, a list of all thesignals, wiring examples and the recommended test reports tobe used in the test bay and during commissioning are containedin the appendices (Section 12).

REB500 1MRB520259-Uen / Rev. A ABB Power Automation Ltd

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June 2000

2. SAFETY INSTRUCTIONS

2.1. Safety instruction flags .............................................................2-2

2.2. General rules............................................................................2-2

2.3. General safety instructions.......................................................2-3

2.4. Instructions for the specific product..........................................2-4

ABB Power Automation Ltd REB500 1MRB520259-Uen / Rev. A

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2. SAFETY INSTRUCTIONS

2.1. Safety instruction flags

Safety instructions in these Operating Instructions are markedas follows:

Danger: Immediate danger due to a mechanical or generalcause. Non-observance can cause serious injury or a fatality.

Danger: Immediate danger because of high-voltage. Non-observance can cause serious injury or a fatality.

Caution: This symbol draws attention to a dangerous situation.Non-observance can cause serious injury to persons or damageto plant.

Note: This symbol draws attention to a potentially damagingsituation.

2.2. General rules

The busbar protection system REB500 corresponds to the latestpractices and guidelines and complies with the recognisedsafety rules. Nevertheless, care must always be taken to avoiddanger.Only use the busbar protection system REB500 when it is inperfect working order and in strict accordance with these Oper-ating Instructions.Dangerous situations can arise if the equipment is used improp-erly, especially if the user changes the configuration.


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2.3. General safety instructions

Danger: Live electrical equipment is always in the vicinity ofREB500. Before working on the system, always ensure that it isimpossible to come into contact with, or even close to live parts.

Danger: The busbar protection system REB500 can initiate op-eration of items of electrical plant (circuit-breakers and isola-tors). Before working on the equipment, always ensure that un-wanted operation is inhibited or has no effect on persons orplant.

Danger: Strictly observe all safety precautions (interlocks, locksand blocking devices), especially those issued for the specificstation.

Caution: Only properly authorised, professionally qualified andcorrespondingly trained personnel, who have also read and un-derstood the operating instructions, may work on the REB500system.


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2.4. Instructions for the specific product

Caution: The REB500 is only designed to protect busbar con-figurations up to quadruple busbars including bypass busbar. Itcan protect 1½ breaker schemes up to a total of 32 busbar sec-tions. A REB500 system can accommodate a maximum of 59bay units.

Danger: Take care never to open the secondary circuits of c.t’sconducting current.

Danger: There is a danger of contact with live parts whenopening REB500 cubicle doors.

Note: Electrostatic discharge can destroy components in theequipment.

Note: Other safety instructions pertaining to particular opera-tions are contained in the respective sections of the operatinginstructions.


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June 2000

3. STRUCTURE, FUNCTION AND TECHNICALSPECIFICATION(BASIC FUNCTIONS AND BUSBAR PROTECTION)

3.1. System structure ......................................................................3-33.1.1. Components of the protection system......................................3-33.1.1.1. Central unit...............................................................................3-33.1.1.2. Bay unit ....................................................................................3-33.1.2. Protection system configuration ...............................................3-53.1.2.1. Central installation....................................................................3-53.1.2.2. Distributed installation ..............................................................3-6

3.2. Operating principle of the protection system............................3-83.2.1. Measurement of primary system currents................................3-83.2.2. Signal detection (binary inputs)................................................3-83.2.3. Signal outputs (binary) .............................................................3-93.2.4. Signal designations ................................................................3-103.2.5. Self-supervision......................................................................3-143.2.5.1. Diagnostic program................................................................3-153.2.5.2. Software supervision..............................................................3-163.2.5.3. Hardware supervision ............................................................3-183.2.5.4. Independent bay unit operation .............................................3-193.2.6. Hardware modules .................................................................3-193.2.6.1. Block diagram of the REB500................................................3-193.2.6.2. Central unit modules ..............................................................3-203.2.6.3. Bay unit 500BU02 ..................................................................3-273.2.6.4. Local control unit (HMI) ..........................................................3-333.2.6.5. High level control systems .....................................................3-353.2.7. Software.................................................................................3-373.2.7.1. Local control unit (HMI) ..........................................................3-373.2.7.2. REBWIN operator program....................................................3-38

3.3. Operating principle of the busbar protection ..........................3-403.3.1. Busbar sections and protection zones ...................................3-403.3.1.1. Busbar configurations ............................................................3-403.3.1.2. Division into protection zones ................................................3-423.3.2. Measuring principle ................................................................3-423.3.2.1. Restrained amplitude comparison algorithm..........................3-443.3.2.2. Phase comparison .................................................................3-473.3.2.3. Differential current alarm........................................................3-483.3.2.4. Neutral current alarm .............................................................3-49


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3.3.2.5. Operating times......................................................................3-503.3.2.6. Enabling the tripping command..............................................3-513.3.3. ITT (intertripping)....................................................................3-523.3.3.1. Busbar image.........................................................................3-533.3.3.2. Supervising isolator positions.................................................3-583.3.4. Bus-tie breaker functions .......................................................3-633.3.4.1. Bus-tie breaker.......................................................................3-633.3.5. REB500 system signals .........................................................3-673.3.6. REB500 blocking scheme......................................................3-71

3.4. Ancillary REB500 functions....................................................3-753.4.1. Ancillary function descriptions................................................3-753.4.1.1. Event memory........................................................................3-753.4.1.2. Test mode ..............................................................................3-753.4.1.3. Installation mode....................................................................3-763.4.1.4. Masking and unmasking devices ...........................................3-763.4.1.5. Inspection and maintenance ..................................................3-773.4.1.6. Time synchronisation .............................................................3-793.4.1.7. Options...................................................................................3-80

3.5. Technical specification...........................................................3-803.5.1. Data Sheet .............................................................................3-80


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3. STRUCTURE, FUNCTION AND TECHNICALSPECIFICATION(BASIC FUNCTIONS AND BUSBAR PROTECTION)

3.1. System structure

3.1.1. Components of the protection system

The digital busbar protection REB500 is divided into severalhardware units. Bay units measure the line and bus-tie breakercurrents and may be installed close to the respective c.t’s. Theycommunicate with the central unit via an optical fibre bus. Thecentral unit processes the current signals measured by the bayunits and distributes the tripping signals back to the bay units inthe event of an internal fault.

3.1.1.1. Central unit

A central unit is housed in a 19" casing (up to 3 casings in largestations) containing a interconnecting bus plane (see Section3.2.6.2), a local control unit and several hardware modules.

Central Unit

ABB Power Automation Ltd REB500

CE

Figure 3.1 Front view of a central unitDepending on the busbar configuration, up to 20 hardware mod-ules are inserted into a central unit.

3.1.1.2. Bay unit

A bay unit is housed in a 1/3 size 19" casing and has the follow-ing main features:

• Single self-contained unit

• 2 basic versions:

- 4 x I (current measurements) + 16 in/out (binary inputsand outputs)


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- 4 x I (current measurements) + 4 x U (voltage measure-ments) + 16 in/out (binary inputs and outputs) + redun-dant auxiliary supplies

• Different semi-flush mounted versions:

- Basic version with or without local HMI

- Version for conventional switchpanel mounting

Basicversion

Basic versionwith HMI

Version for conventionalswitchpanel mounting

Figure 3.2 Bay units for alternative types of semi-flushmounting

Figure 3.3 Rear view of bay unit (example for I and U meas-urements and redundant supplies)


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3.1.2. Protection system configuration

The protection system comprises a central unit and as many bayunits as there are switchgear bays in the station. The bay unitscan be either installed in the control and protection cubicles as-sociated with the individual bays or collectively in the central re-lay room. Communication between the bay units and the centralunit is via an optical process bus. The central unit collects all thedata and executes the protection algorithms and auxiliary func-tions.

The process bus connecting the bay units to the central unit isdivided into segments. Up to 10 bay units can be connected to asegment. (Only nine can be connected to the first segment, be-cause the central unit’s binary input/output module 500BI001occupies the tenth.) Each bus segment has its own CPU masteror slave processor, a master or slave bus administrator and upto two star-couplers.

The busbar protection has capacity for up to 59 bay units, i.e. upto six bus segments.

The central and bay units used for centralised and distributedconfigurations are basically the same.

3.1.2.1. Central installation

Depending on the size of the busbar system, the protection isaccommodated in one or several cubicles. In this case, the bayunits are fitted into mounting plates. Both central and bay unitsare mounted in hinged frames in the cubicles for ease of access.

Figure 3.4 Basic layout of a centralised REB500 protectionsystem


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Advantages of centralised installation

• Modernisation of old stations. The REB500 is installed inplace of the existing busbar protection scheme.

Centralised system with 1 to 12 BU02

Central unit (CU)

Air vent

Equipment fitted from the front Equipment fitted from the rear

DC terminal block

DC terminal block

DC terminal block

DC terminal block

DC terminal block

AC terminal block

AC terminal block

AC terminal block

AC terminal block

AC terminal blockAux. supply unit

Aux. supply unit

Figure 3.5 Example of the equipment cubicles in a central-ised busbar protection system

3.1.2.2. Distributed installation

The bay units are installed in the control and protection cubiclesassociated with the individual switchgear bays and the centralunit is located on its own normally in a relay equipment room.


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Figure 3.6 Basic layout of a REB500 protection system withdistributed bay units

Control and protection cubicles close tothe switchgear bays

REB500 central unit

REB500 bay unit

REB500 bay unit

Feeder protection Feeder protection

Control unit Control unit REC REC

REL REL

Central unit Bay unit 1 Bay unit 2

Figure 3.7 Equipment cubicles for a busbar protection sys-tem with distributed bay units

Advantages of distributed installation

• Short cables runs between the primary process and the bayunits

• All control and protection equipment close to the associatedbay


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• Short channels of communication between the devices

• Simple maintenance and testing

3.2. Operating principle of the protection system

3.2.1. Measurement of primary system currents

The current parameters are processed digitally by the REB500busbar protection system. To this end, the feeder currents aresampled 48 times per period. At a power system frequencies of50 Hz and 60 Hz, this corresponds to sampling rates of 2.4 kHzand 2.88 kHz respectively.

Fourier transformation of the current signal samples takes placein the bay units so that only the fundamentals are subsequentlyprocessed. The real and apparent components of the funda-mental are then derived and transferred to the central unit.

3.2.2. Signal detection (binary inputs)

Opto-couplers electrically insulate all the binary inputs.

They pick up when the input voltage remains above 80 % of therated auxiliary voltage for at least 20 ms and reset when it isbelow 65 % for longer than 20 ms.

The standard binary inputs are all equipped with anti-bounce fil-ters. The software anti-bounce filter has no influence on a sig-nal’s time stamp, i.e. the time stamp is determined by the firstoccurrence of the signal at the input of the opto-coupler.

Time stamp

Anti-bounce filter time

Opto-coupler input signal

Internal REB500 signal after the anti-bounce filter

The anti-bounce time for the special signals below is set to theminimum of 2 ms instead of the standard time (normally 20 ms)set generally for the system:

• All disturbance recorder input signals “167nn_Start DR_x”and “36705_General Start DR”


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• Breaker failure input signals “137nn_Start BFP_Lx” and“13705_External Start BFP”

• “31805_External release BB zone” and “11605_External re-lease Trip”

• The signals “11510…11525_Supervison aux. voltage_x” areset to a fixed anti-bounce time of 10 ms.

Caution: Should several signals be configured for a commonopto-coupler input and one of them have a minimum anti-bounce time of 2 ms, then 2 ms applies for all the signals.This kind of configuration should be avoided wherever possible.

A distinction is made between input signals with a slow responseand those with a fast response. Internally, REB500 processesthe process bus signals in fast and slow cycles according to theirpriority.

Signal response:

slow: These signals must be maintained at the binary inputfor at least 128 ms plus the anti-bounce time and areprocessed by the slow cycle.

fast: These signals must be maintained at the binary inputfor at least 8 ms plus the anti-bounce time and areprocessed by the fast cycle.

3.2.3. Signal outputs (binary)

The bay units generate two kinds of binary output signals, trip-ping commands and logic signals. The central unit only gener-ates logic signals.

This takes place in accordance with the logic configured in theprocessors of central and bay units. To distinguish between trip-ping commands and logic signals, the names of tripping com-mands are written in upper case characters.

Output signals can be assigned to auxiliary output relays to ac-tuate either a tripping or signalling circuit. As a safety precaution,it is impossible to assign tripping commands and logic signals tothe same output relay, i.e. tripping commands can only be com-bined with other tripping commands and logic signals with otherlogic signals. For example, the signals “21305_Trip” and“21105_EXTERNAL TRIP” cannot be configured to operate thesame output contact.


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With regard to the rating of their contacts, the bay unit outputsCR09 to CR16 are designed to be used as tripping channelswhile outputs CR11 to CR16 are rated to directly operate circuit-breaker tripping coils. Output CR01 to CR08 are suitable for re-laying logic signals.

The intertripping output “21110_TRIP” is always configured andis used by the following protection functions:

- Busbar protection tripping

- Breaker failure tripping t2

- End zone fault tripping (c.t’s on the busbar side)

- External tripping of the protection zone

Signal “21805_In service” is configured to operate from CR01.

Refer to Section 12 for the recommended configuration.

3.2.4. Signal designations

The REB500 configuration assigns the signals to predefined in-puts and outputs.

The designations of the signals are determined according to thefollowing convention:


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Abbreviation categories

BBP_ Busbar protection signal

BFP_ Breaker failure signal

BU_ Bay unit

CU_ Central unit

DR_ Disturbance recorder signal

EFP_ End fault protection signal

I Input

O Output

OCDT_ Time-overcurrent protection signal

PDF_ Circuit-breaker pole discrepancy protection signal

SYS_ General signal

SYS_INT Internal system signal

UV_ Low voltage check feature

Table 3.1 Abbreviations used for the different signalcategories

Function abbreviations

Busbar protection BBP

Breaker failure protection BFP

End fault protection EFP

Time-overcurrent protection OCDT

Disturbance recorder DR

Circuit-breaker pole discrepancy protection PDF

Low voltage check feature UV

Table 3.2 Abbreviations used for the various functions


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Categorynumber

Namecategory

Upper and lower case rules

1 Signal First letter upper case, other letters of thefirst word lower case.

Subsequent words conform to nationalupper and lower case conventions.

Functions such as BBP are always in up-per case letters.

Statuses such as “Open” have an uppercase first letter and the remainder writtenin lower case characters.

Phase designations are written in uppercase letters, e.g. L1.

Parameters such as t1 are lower case.

2 Input signalsthat can initi-ate tripping

The same rules as for category 1.

Secondary effects are in upper case let-ters, e.g. TRIP.

3 Direct trip-ping signals

All words and letters in upper case char-acters

4 Output sig-nals used fortransfer trip-ping

As for category 1, in addition the effect iswritten completely in upper case charac-ters.

Table 3.3 Relationship between category numbers and sig-nal names


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Syntax rules for signal names (examples)

Input Start BFP L1_1 Name category 1

1. Effect 2. Function 3. Phase 4. Order

Output BFP Trip L1 Name category 1

1. Function 2. Effect 3. Phase (target)

Input External TRIP BB zone Name category 2

1. Effect 2. Location (e.g. zone)

Output BFP TRIP Name category 3

1. Function 2. Effect

Output BBP remote TRIP Name category 4

1. Function 2. Target 3. Effect

Table 3.4 Signal name syntax


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Category Protection function

Signal function Sequential number

1 BU_I 0 INT 1 TRIP 05

2 BU_O 1 SYS 2 Block command 10

3 CU_I 2 BBP 3 Tripping signal 15

4 CU_O 3 BFP 4 Blocking signal 20

5 SYS 4 EFP 5 Bus image etc.

5 OCDT 6 Control

6 DR 7 Start

7 PDF 8 General alarm

8 UV

Example of a signal number: 2 3 3 05 = BFP Trip t1

Table 3.5 Significance of the signal number digits

3.2.5. Self-supervision

To ensure the maximum possible reliability, the REB500 isequipped with a self-supervision function which enables it to re-spond quickly to any hardware (HW) or software (SW) errors.Some, such as an error in transmission via the process bus, onlyaffect a single data set and are generally of a transient nature. Aserious error would mean, for example, that an essential func-tion could no longer be guaranteed. It is especially important todetect errors of this kind and to take the corresponding precau-tions, which can include blocking the protection functions andtripping outputs.

The self-supervision and diagnostic function ensures the highavailability of the busbar protection. Errors and defects are im-mediately detected and signalled so that corrective action canbe taken without delay.


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3.2.5.1. Diagnostic program

The diagnostic program is an important part of the busbar pro-tection software. Its task is to manage (start and stop) all theother applications (e.g. protection functions and binary inputsand outputs) and process the data of the self-supervision func-tion.

The system SW is object oriented, i.e. it is divided into subsys-tems that perform specific applications (protection functions, bi-nary inputs and outputs, database controller etc.). The structureof the diagnostic program reflects the structure and distributedarchitecture of the protection system, i.e. it is also distributedbetween every module of the central unit and bay units having amicroprocessor.

...

Higher levels

Enabling signal

Status

Intermediate level of diagnostic program

Application status

Status

Enabling signal

Status

Enabling signal

Lower level (1) Lower level (n)

Figure 3.8 Structure of the self-supervision functionEach level in the structure of the diagnostic program reports thestatus of the applications at the same or lower levels to the nextlevel up. Enabling (release) signals are distributed from top tobottom. As soon as the diagnostic program detects a criticalfault, the corresponding status is reported upwards and thedownwards distribution of the enabling signal blocked. The pro-tection system thus propagates the blocking of the enabling sig-nal to block all tripping outputs. In the case of critical faults, theprotection system is shut down and restarted.


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3.2.5.2. Software supervision

Programming language in safety systems

The choice of program development method and programminglanguage is extremely important for digital protection systems.The digital busbar protection REB500 was developed using theprogramming language “Ada” which was especially written forreal-time and safety applications.

Apart from special features that enhance the reliability of the re-sulting program (e.g. abstraction principle and strict data typerules), Ada facilitates “exception processing” which means thatcritical situations which occur while the system is busy with nor-mal program execution are detected and immediately proc-essed.

Supervising the applications

The diagnostic program can control applications by detectingstatus changes (e.g. initialisation and stopping at the right in-stant). The applications report their statuses (e.g. initialisationfinished, processing finished or error detected). Using statuschanges to supervise the applications means that an applicationthat has been started must report back to the diagnostic pro-gram within a given time.

A hard-wired watchdog per microprocessor which the programshave to reset at regular intervals supervises the entire SW.Should a watchdog not be reset, the watchdog timer times outand initiates a hardware reset.

Supervision of data transfer via the process bus

A number of supervised criteria ensure the integrity of the datatransferred via the process bus. All data transferred via the pro-cess bus are subject to a cyclic redundancy check according tothe TC57 telecontrol algorithm. Thus in a block of up to 64 Bit,five Bit errors can be detected. Data are also processed usingthe Manchester code which further raises the standard of secu-rity.

Supervision of the protection functions

The operation of every application is synchronised and a timestamp is attached to all analogue signal samples and binary sig-nals. Before determining a differential current, a check is per-formed to make sure the samples have the same time stamp.Should this not be the case, the samples concerned are notevaluated.


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Processing and supervising the binary inputs

Every binary input is equipped with its own anti-bounce software.As a rule, the status of a signal is considered valid for process-ing if it persists 20 ms after its first incidence.

The binary inputs are also supervised with respect to oscilla-tions. If the status of an input changes five times in 100 ms, theinput is marked as “invalid”. In this case, the signal is processedsuch that the reliability of the system is assured, i.e. invalidblocking inputs are assumed to be active.

Enabling binary outputs

To achieve the maximum reliability of the system, every trippingcommand has an associated enabling signal and should the di-agnostics program detect an HW or SW error, it suppresses theenabling signals for the binary outputs, i.e. the tripping outputsare inhibited.

Error messages in the event list

All errors and defects detected by the self-supervision functionare processed by the diagnostics program and recorded asevents. These are classified as “major errors” if the proper op-eration of the protection functions can no longer be guaranteed.

In such cases, the system is automatically restarted. All the out-put channels are blocked, the protection devices are no longerstanding by and the green LED’s on the local control units flash.Table 4-1 “Error messages generated by the operator programREBWIN” in Section 4.6. “Error messages” lists the possibleevents recorded by the diagnostics program.Errors that do not endanger the proper operation of the protec-tion functions are classified as “minor errors”.

Error messages generated by the REBWIN operator program

The protection system errors that are displayed in a REBWINwindow are described in Table 4.1 “Error messages generatedby the operator program REBWIN” in Section 4.6. “Error mes-sages”. Some can be rectified by restarting either the operatorprogram or the protection system.

Starting or restarting the system

When the self-supervision function or the diagnostics programrestarts the system or a part of it, the procedure is signalled onthe local control unit. The blocked status of the system is sig-nalled by the flashing yellow LED on all the units and on the HMI.


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While the system is starting, all the LED’s flash and the SW ap-plications are indicated by a designation (e.g. MPL, TIM etc.).The successful start-up of the system can be seen from the factthat the main menu is displayed on all the units and that the sig-nal “41810_In service” is set.

3.2.5.3. Hardware supervision

Supervising the auxiliary supplyThe power supply units in the central and bay units are designedfor an input voltage in the range 36 VDC to 312 VDC. The threeoutput voltages (rated +5 V and ±12 V) are supervised with re-spect to their permissible variations. An auxiliary supply voltagethat is out of tolerance counts as a major error, i.e. the protectionsystem is shut down and restarted.

Supervision of the analogue circuitsThe analogue circuits between the secondaries of the inputtransformers for current signals and voltage signals where con-figured and the A/D converters are duplicated and the two cir-cuits supervise each other. A discrepancy between them is de-tected by the analogue circuit supervision function which thenblocks the respective bay unit.

A/D (analogue-to-digital) convertersTo supervise the accuracy of the A/D converters and the associ-ated components, they are also made to convert reference volt-ages (7.5 V and 0 V) each time they convert the analogue sig-nals. The resulting digital values of the reference voltages arethen compared with respect to permissible upper and lower limits.

Microprocessor program and main memoriesAll main memories are tested by writing and then reading a testpattern.

Supervision of the tripping relay coilsThe circuits controlling the six bay unit tripping relays CR11 toCR16 are arranged such as to supervise the integrity of the trip-ping relay coil.

Parts not covered by the self-supervision function

It is impossible to supervise all parts of the protection chain, e.g.the binary input circuits. It is also advisable to install an externaltrip circuit supervision system.


3-19

3.2.5.4. Independent bay unit operation

In the event of failure of the central unit or the optical process bus,the bay units continue to perform the local protection functionsbreaker failure, end zone fault and time-overcurrent and also tomaintain the disturbance recorder function. This, however, is anemergency operating mode subject to limitations:

• As the bay units cannot communicate with the central unit, nointertripping is possible.

• The REBWIN operator program and local HMI are severely re-stricted and response can be extremely slow. Events and dis-turbance recorder records can be read, but none of the binaryinputs and outputs function and currents and voltages can onlybe displayed on the local control unit (LMI).

The bay units automatically restart themselves as soon as commu-nication is restored.

The independent operation of the bay units is an emergency oper-ating mode and not intended to enable them to be used as protec-tion devices without a central unit. It only serves to bridge the timeuntil the central unit or the communication bus is restored to opera-tion.

3.2.6. Hardware modules

3.2.6.1. Block diagram of the REB500

CIM

C

E

DC

DC

DC

CPUmodule

CPUmodule

CPUmodule

SCS/SMSinterface

RS 232interface

Real-timeclock

Star-coupler

BinaryI/O

Star-coupler

BinaryI/O

Local HMI

Electricalinsulation

Filter

BinaryI/O register

A/D

Filter

CPUE

C

Opticalinterface

DC

DC

DSPDP

mem

Central unit (CU)Bay unit (BU02)

Local HMI

HEST 005026 C

Figure 3.9 Block diagrams of bay and central units


3-20

3.2.6.2. Central unit modules

The following modules can be fitted in a central unit:

Module Type Function

Master CPU 500CMP04 Processor module for up to 9 bayunits with a process bus interface,RAM, local control unit interfaceand non-volatile memory (flash)

Slave CPU 500CSP04 Extension processor required per10 additional bay units

Binary I/O module 500BIO01 I/O module with 12 opto-couplerinputs and 9 relay outputs

Optical star-coupler 500SCM01 Module with 5 transmit/receive opti-cal pairs.

Communication inter-face (communicationCPU)

500CIM04 Communication processor for LONor IEC 60870-5-103 interfaces (op-tional)

Transition module 500TRM02 Transition module for CMP andCSP processors

Transition module 500TRM03 Transition module for CIM commu-nication processors (optional)

Bus controller 500MBA01 Manages and controls the transferof data via the respective processbus segment

Power supply unit 500PSM03 Auxiliary supply

Table 3.6 Central unit modules

Power supply unit 500PSM03

The power supply unit is a DC/DC converter with electrical insu-lation between input and output and an output power of 100 W.It has an input voltage range of 36 VDC to 312 VDC (i.e. 48 V-25 %...250 V +25 %) without any switching of ranges. Thestandard output voltages are +5 VDC and ±12 VDC. The toler-ances of the output voltages are continuously monitored.

The input of the power supply unit 500PSM03 is protected by a6.3 A/250 V slow fuse. The current surge when energising thePSM03 is limited to 10 A. The use of an external miniature cir-cuit-breaker (m.c.b.) Type S282 UC-K 6 is recommended.

There is an on/off switch on the front of the power supply unit500PSM03 which must be in the on position when the protectionis in operation. In the off position, the PSU is on standby.


3-21

Caution: A power supply unit may only be withdrawn or in-serted when the power supply is switched off. To withdraw aunit, turn off the switch on the power supply unit and disconnectthe green power supply cable connector. It is not sufficient tosimply switch the unit off at the switch. Other modules may onlybe withdrawn or inserted when the power supply unit500PSM03 is switched off.

The power supply unit 500PSM03 has three LED’s:

• Green LED: lights providing all the output voltages are withintolerance and extinguishes in the event of a short-circuit oroverload of one or several output voltages.

• Yellow LED: lights when one of a pair of redundant powersupply units has failed (corresponds to operation of the“Warning” signalling relay).

• Red LED: lights when one of the modules in the respectiverack (including power supply unit) has failed (corresponds tooperation of the “Alarm” relay).

1

2

3 Alarm: 1-3: Normal operation1-2: Alarm or not in

operation

4

5

6Warning: 4-6: Normal operation 4-5: Warning or not in

operation

Contacts:

Normally only the “Alarm” contact is connected.

Redundancy:

When two 500PSM03 power supply units are operating in par-allel, their outputs are connected via diodes such that the supplyto the protection modules is maintained should one supply unitfail.

A power supply unit 500PSM03 does not require any mainte-nance.


3-22

Front plane bus 500CUB02 (standard)

The sockets for the plug-in modules are mounted and intercon-nected on the front plane bus. The maximum capacity of thefront plane is:

• 2 power supply units

• 4 processor units

• 12 modules of other types10 RS485 process bus (MVB) interfaces are provided.

Front plane bus 500CUB01

The front plane bus 500CUB01 is only used when the number ofbay units exceeds 29. The sockets for the plug-in modules aremounted and interconnected on it. The maximum capacity of thefront plane 500CUB01 is:

• 2 power supply units

• 6 processor units

• 10 modules of other types10 RS485 process bus (MVB) interfaces are provided.

Processor module 500CPU04

There are two 25 pin Sub-D serial interfaces, two pushbuttonsand eight LED’s on the front of the module. The Sub-D inter-faces and the pushbuttons are not used during normal operationand are covered. The LED’s serve the following purposes:

FAIL (red) signals a hardware fault.

STAT (yellow) only lights when the program is not running.

RUN (green) lights when the program is running.

SCON (green) indicates the master processor module and canonly be lit on one module in the protection sys-tem.

LAN (green) Not applicable to REB500.

FUSE (green) Not applicable to REB500.

SCSI (green) Not applicable to REB500.

VME (green) signals data transfer via the VME bus.

Apart from the microprocessor and the main and programmemories, the module has four sockets for “industry pack” de-


3-23

vices. An industry pack is a small sub-module measuring ap-proximately 80 x 35 mm that is mounted directly on a processormodule to expand its functionality for a specific application. Theindustry pack interface has standardised mechanical and electri-cal characteristics. The following two types of industry packs areused in the REB500 busbar protection.

500HPBI01

Every plug-in unit requires a special interface module andcommunication memory (RAM) to enable it to transfer data viathe process bus. The interface function is performed by an“application specific integrated circuit” (ASIC). The communi-cation memory is basically a register for process bus data.

500IPS01

This module includes primarily the serial interface for the localcontrol unit.

Part of engineering a project is determining the components tobe fitted in the processor module. There are a number of alter-natives depending on the size of the system.

One processor module with one or several sub-module functionsas CPU. It performs the protection functions at station level.Where a busbar scheme only has a single communication bussegment, only one master CPU is used (CPU master processor= CMP). Schemes with several communication bus segmentshave one master CPU and several slave CPU’s (CPU slaveprocessor = CSP). Only one processor per rack may be config-ured as CMP, i.e. jumper J1 is inserted in only one processor).


3-24

Alternative CPU arrangementsSub-module sockets and jumpers

CMP

500IPS01

500PBI01

J1

CSP

500PBI01

J22

Figure 3.10 Alternative CPU arrangementsCMP: CPU master processor (500CPU04)

Jumper J1 inserted (VME bus master)Jumper inserted in J22 1-3, 2-4 (VME bus +5 V STDBY)

CSP: CPU slave processor (500CPU04)Jumper J1 not insertedJumper J22 inserted in 3-5, 4-6 (SRAM on-board)

When jumper J22 on the CMP module is inserted in 1-3, 2-4, theevent memory supply is supported by the condensers on the500CUB02 front plane.

These condensers are not fitted on the 500CUB01 front planeand the alternatives are either to operate without buffering of theevent memory supply or to use the battery on the CMP board byinserting jumper J20 into 3-5, 4-6 (see paragraph “Failure of theauxiliary supply batteries” below).

Bus controller (standard version)The transfer of data via the process bus segments is controlledby bus controller processor. As is the case with the CPU proces-sors, there can be master (MBA) and slave (SBA) bus control-lers. Generally, a 500MBA01 is used.


3-25

The bus controller 500MBA01 is connected by an optical fibrecable to the process bus.

MBA SBA

no sub-modules no sub-modules

Figure 3.11 Bus controllers (standard version)MBA: Master bus controller (500MBA01)

SBA: Slave bus controller (500MBA01)

Bus controller (Version 2, scarcely used)The combination of modules 500CPU01, 500TRM02 and500PBI01 can be used as bus controller instead of a500MBA01.

MBA

J1

J20500PBI01

500PBI01

SBA

no sub-modules

Figure 3.12 Bus controllers (alternative 2)MBA: Master bus controller (500CPU01)

Jumper J1 insertedJumper J20 inserted in 3-5, 4-6 (SRAM on-board)

SBA: 500MBA01


3-26

Failure of the auxiliary supply, batteries

Maintenance-free condensers are fitted in the bay unit and the500CUB02 central unit which supply the disturbance recorderand event memories for 24 hours in the event of a auxiliary sup-ply failure.

A lithium battery is mounted on each of the 500CPU04 units(CMP and CSP) for supplying the memory modules which, how-ever, is not used, and there is also a system clock with inte-grated lithium battery. The clock on the CSP boards is not used,but the one on the CMP provides the date and time for REB500in the event of an auxiliary supply failure. The level of charge leftin the lithium batteries cannot be measured and their life de-pends on a number of factors such as ambient temperature andhow long they are switched on, but is typically more than 10years.

The clock is only used to provide the date and time for initialisingthe time tagging of REB500 events when switching the centralunit on. The only consequence of the lithium battery being un-able to maintain the clock supply should the auxiliary supply failwould be that the absolute date and time would be incorrect thenext time REB500 was started.

500TRM02 transition module

The sub-modules on a 500CPU04 processor module are con-nected by ribbon cables to the transition module (500TRM02)and the bus board.Every 500CPU04 processor module has a transition modulenext to it.

Note: A 500CPU04 processor module and its associated500TRM02 transition module must be withdrawn from the cas-ing together.

Star-coupler module 500SCM01

The star-coupler module 500SCM01 converts the electrical pro-cess bus signals into optical signals and vice versa. Each oneprovides five optical transmit/receive pairs which are connectedto five bay units by optical fibre cables. The transfer of data issignalled by a yellow LED for transmit and a yellow LED for re-ceive. Both must light when the protection is in operation.


3-27

Binary I/O module 500BIO01

The binary I/O module 500BIO01 provides opto-coupler inputsfor signals from the primary system process and auxiliary relaysfor sending signals and commands to it. It has a complement of12 opto-coupler inputs and 9 auxiliary relay outputs. Both inputsand outputs electrically insulate the internal electronics from theexternal circuits.

The number of I/O modules installed in the central unit is deter-mined when engineering the specific project. A maximum of twoinput/output modules can be configured.

3.2.6.3. Bay unit 500BU02

A 500BU02 bay unit is designed as a single self-contained unit.

Two basic versions are available:

500BU02-1: 16 binary inputs16 binary outputs4 c.t. inputs (IL1, IL2, IL3, IL0)

500BU02-2: 16 binary inputs16 binary outputs4 c.t. inputs (IL1, IL2, IL3, IL0)4 v.t. inputs (UL1, UL2, UL3, UL0)Redundant power supplies


3-28

* with redundant power supply

Bay units

500 BU02_1 (4 I, 16 I/O)

500 BU02_2 (4 I, 4 U*, 16 I/O)

0

0

1U

2

0

0

4

5

7

8

10

11

UL1

UL2

UL3

UL0

+

-1

2

R

V.t.’s

redundantpower supply

1

2

3

1

5

0

1

5

0

5

6

1

5

0

7

8

9

1

5

0

10

11

12

IL1

IL2

IL3

IL0

I

12

P +

-

Power supply

C.t.’s

HMI interface

Prozess bus

Binary outputs

32

1 C

D

Prozess bus

Binary inputs

B

A

HEST 005028 C

Inputs and outputs provided

Figure 3.13 Bay units 500BU02-1 and 500BU02-2


3-29

Two versions of the bay unit for semi-flush mounting are avail-able.

Version for conventional switchpanel mounting:

This version of the bay unit has a frontplate and a local HMI andis designed for fitting into switchpanel cut-outs. It is used primar-ily for distributed REB500 systems.

Basic version with or without local HMI:

The basic version does not have a frontplate. A connector isprovided for a separately mounted HMI. This version is usedprimarily for centralised REB500 systems, because the bay unitsare generally installed in a cubicle and are not visible from outside.

Basicversion

Basic versionwith HMI

Version for conventionalswitchpanel mounting

Figure 3.14 Bay units for alternative types of semi-flushmounting

Bay unit power supply:

The auxiliary power supply is provided by a DC/DC converterwith electrically insulated input and outputs and a rated outputpower of 9 W. The input voltage range is 36 VDC to 312 VDC(i.e. 48 V –25% to 250 V +25%) without the need for switching oradjustment.

Protecting the input of each 500BU02 by an external miniaturecircuit-breaker (m.c.b.) Type S282 UC-K (2 A) is recommended.

An on/off switch is located on the front of the unit and a greenLED lights continuously providing the output voltages are withintolerance. The LED extinguishes in the event of a short-circuit oroverload.

Redundant auxiliary supply units are possible (optional).


3-30

Caution: The on/off switch on the power supply unit does notisolate the unit from the input supply. Switch off the m.c.b. to dothis.

Binary inputs and outputs on the bay unit 500BU02

Inputs:

Signal voltage 48…250 VDC, 8 groups of 2 inputs. The effectivepick-up voltage is set by configuring the software.

Auxiliary relay outputs (rupture current)

CR01…CR08 Signalling contactsmax. 0.5 A at U ≤ 50 VDCmax. 0.1 A at U ≤ 120 VDCmax. 0.04 A at U ≤ 250 VDC

CR09…CR16 Tripping contactsmax. 1.5 A at U ≤ 50 VDCmax. 0.3 A at U ≤ 120 VDCmax. 0.1 A at U ≤ 250 VDC

The rupturing currents given below can be achievedby externally wiring two contacts in series.

CR09…CR16 Two tripping contacts in seriesmax. 5 A at U ≤ 50 VDCmax. 1 A at U ≤ 120 VDCmax. 0.3 A at U ≤ 250 VDC


3-31

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

OC01

OC02

OC03

OC04

OC05

OC06

OC07

OC08

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

OC09

OC10

OC11

OC12

OC13

OC14

OC15

OC16

Binary inputsA

B

500BAP01

OL01

Tx

Rx

E

Process bus

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

1

2

3

4

5

6

7

8

9

10

11

12

13

14

15

CR01

CR02

CR03

CR04

CR05

CR06

CR07

CR08

CR09

CR10

CR11

CR12

CR13

CR14

CR15

CR16

Binary outputs

C

D

500BOR01

HEST 005050 C

Figure 3.15 Binary inputs and outputs

C.t and v.t. terminals on the 500BU02

A bay unit has terminals for connecting 4 c.t’s.

The primaries of the input transformers have tappings for rated cur-rents of 1 and 5 A. There are thus three screw terminals per c.t.

Only version 500BU02-2 of the bay unit is equipped with screw ter-minals for v.t’s.


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The rated voltage of the v.t. inputs is 200 V. The effective inputvoltage is set by configuring the software. Therefore there areonly two screw terminals per v.t.

0

0

1U

2

0

0

4

5

7

8

10

11

UL1

UL2

UL3

UL0

-

1

2

R

V.t.’s

Redundantpower supply

500UTM01

1 A terminal

5 A terminal1

2

3

1

5

0

1

5

0

4

5

6

1

5

0

7

8

9

1

5

0

10

11

12

IL1

IL2

IL3

IL0

1 2

P +

-

Power supply

500PTM01

C.t.’s

HEST 005029 C

Optional

Figure 3.16 C.t and v.t. terminals

Process bus connectors on the 500BU02

The process bus input and output connectors are located abovethe binary inputs on the rear of the bay unit.

Analogue section of the 500BU02

The main task performed by the analogue section is to process8 analogue input signals. The A/D converters have a range of 16Bit and a sampling rate of 2'400 Hz per channel at a system fre-quency of 50 Hz (2'880 Hz at 60 Hz). The module comprises amicroprocessor, a main memory, a flash program memory and awatchdog. A digital signal processor (DSP) is also included forsignal pre-processing.

Note: A bay unit is a single closed unit. In case of failure, indi-vidual modules are not replaced, but the entire bay unit.


3-33

3.2.6.4. Local control unit (HMI)

The local control unit, which forms part of every central unit andcan optionally be installed in the bay units as well, is equippedwith a four-line LCD, 3 LED’s and 6 pushbuttons. It permits allthe operations that are necessary to be carried out locally andincludes an optical interface for a PC. The optical interface elec-trically insulates the PC from the REB500 devices and preventselectrical interference between the two.

The local control units in both central and bay units indicate thefollowing:

• Current and voltage measurements

• Input and output statuses

• Alarms (generated by the respective bay unit)

• System (or bay unit) settings

• Protection settings for the particular bay

yellow redgreenLED’s:

Optical PCinterface

Figure 3.17 Local control unit (HMI)


3-34

LED’sA LED can be in one of three states: not lit, flashing or continu-ously lit. All LED’s flash while the system is being initialised.

GreenOnce the protection has been initialised and is standing by,the green LED lights continuously in normal operation. If it isnot lit or flashing, the unit is either not switched on or defec-tive.

YellowThe yellow LED is lit while an alarm is active. When an alarm(e.g. differential current or isolator alarm) is first generated,the yellow LED flashes and then lights continuously after it iseither acknowledged by pressing a button or tripping takesplace.

RedA red LED indicates that the protection has tripped. This LEDremains lit until reset by a signal applied to the correspondingbinary input or via the submenu Reset latching.

LCD

When an alarm or a trip occurs, the functions of the three LED’sare displayed on the first line and the event is described in moredetail on the remaining three lines. The lines show informationaccording to the actual level in the menu structure.

The background illumination of the LCD on the local control unitswitches off if no buttons are pressed for about 10 minutes. Itswitches on again as soon as a button is pressed. This first op-eration of a button does not delete any information on the dis-play.

Pushbuttons

The six pushbuttons serve mainly to navigate through the menustructure. If the background illumination of the LCD is switchedoff, pressing any button switches it on again. If it is already lit,pressing a button acknowledges the information being displayedon the local control unit.

Button E

Press button E to go to the next menu down.


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Button C

Press button C to return to the main menu. If Reset latch-ing is the current menu, pressing this button resets any re-lays that are latched.

Arrow buttons

The buttons marked “↑” and “↓” are for scrolling through dis-plays of information needing more than four lines.The buttons marked “←” and “→” are for moving through themenus item by item.

Entering a bay unit ID

See Section 8.3.2.

3.2.6.5. High level control systems

Station automation system

By means of communication module 500CIM04, the REB500busbar protection can be integrated in a station automationsystem (SCS) or a station monitoring system (SMS).

The system supports two station bus protocols LON and IEC60870-5-103 (see Section 11.8 “Interbay bus (IBB) connection”).

Optical interface

An optical serial interface is provided on the local control unit ofboth central and bay units for connecting a PC. Using the PCand the operator program REBWIN running under MocrosoftWINDOWS 98 or NT, the entire protection system can be con-figured, settings made or changed and its correct operationtested.

2 electrical-to-optical converters and 2 optical fibre cables areneeded for the connection between REB500 and the PC. Thecables have either plastic or glass cores depending on the dis-tance.

Optical fibre cables

Distances ≤≤≤≤ 30 m

Optical fibre cables with plastic cores are permissible for dis-tances up to 30 m. Complete cable kits (2 converters and ca-bles) can be ordered as accessories under the following num-bers:


3-36

Type Order No. Part No.

YX216a-1 (4 m) 7433 1640 – AA HESG448522 R1

YX216a-1 (10 m) 7433 1640 – BA HESG448522 R2

YX216a-1 (30 m) 7433 1640 – CA HESG448522 R3

Distances ≥≥≥≥ 30 m

Optical fibre cables with 62.5/125 mm glass cores and appropri-ate converters such as Hirschmann OZDV 2451 G (HirschmannOrder No. 943 299-021) are recommended for distances greaterthan 30 m.

The converter at the REB500 end should be configured as DCEand the one at the PC end (with 25 to 9 pin adapter) as DTE.

Modem link

The PC and REBWIN can also be coupled to the REB500 pro-tection system over long distances using a modem (see Section11.9.3 “Modem link”).

Serial interface

In addition to the optical connectors on the control unit on thefront, the PC can also be connected to the serial interface at therear of the REB500 central unit. This should be used for longdistance communication via either optical fibre cables or a mo-dem.

For reasons of safety, only one of the two connectors may be inoperation at any one time, either the local connection on thefront of the units (HMI) or the remote communication connectorCMP at the rear. When REB500 is started, both interfaces arestanding by. As soon as REBWIN is started on the PC, it estab-lishes communication via the interface it is connected to and theother one is disabled and remains so until the first connection isshut down (REBWIN is closed on the PC). Both interfaces arethen once again standing by and waiting for REBWIN to estab-lish a new connection.

Both modem and optical fibre cable links are connected to theconnector (25 pin Sub-D) marked SERIAL PORT 2 on the CMP.The port is configured for 9600 Baud, 8 Bit, no parity and 1 stopBit and cannot be changed (see Section 11.9.1 “Serial interface(RS232)”).


3-37

3.2.7. Software

3.2.7.1. Local control unit (HMI)

The information regarding the current and voltage measure-ments, the statuses of inputs and outputs, alarms, system set-tings (central unit only) and the settings of the protection func-tions that have been configured can be viewed on the localcontrol unit on either central or bay units, but not changed. Thecorresponding data are organised in menus and submenus. Thedesired menu item is accessed and selected using the left “←”and right “→” arrow buttons. If there is room for only a part of amenu on the display, use the arrow buttons marked “↑” and “↓”to see the parts that are not visible.

The menu structure of central and bay units is basically thesame with additions on the central unit for general system set-tings and on the bay units for the menu items of specific bay unitfunctions.

Menu structure of the central unitAlarmsTripsReset latchingCentral unit

Meas. var.Bus zones

Bus zone 1Diff. cur. alarm


... (other bus zones as configured)Inputs

Slot 19 (where fitted)Slot 20 (where fitted)

OutputsSlot 19 (where fitted)Slot 20 (where fitted)

Global valuesSettings

System responseBusbar protection

PhasesNeutral

Bay unitsBay unit 1

Meas. var.CurrentsVoltagesInputs

Slot 5Slot 4 (where configured)

Outputs


3-38


Circuit-breakersBreaker designation... (where configured)

SettingsBBPBFP (where configured)OCDT (where configured)EFP (where configured)PDF (where configured)

Bay unit 2See bay unit 1

... (other bay units as configured)

Menu structure of the bay unitAlarmsTripsReset latchingSettings

Global valuesSystem responseBBP

Phases Neutral current Overcurrent enable

BFP (where configured)OCDT (where configured)EFP (where configured)PDF (where configured)

Measured variablesCurrentsVoltagesInputs

Slot 1Outputs

Slot 1Circuit-breakers

Breaker designation... (where configured)

3.2.7.2. REBWIN operator program

The REBWIN operator program running on a PC and connectedvia the optical serial interface on the central unit or a bay unit ismuch more convenient to use than the buttons on the local con-trol unit. It also permits parameters and settings to be changed.The corresponding menu items are also arranged in menus andsubmenus. The items of the main menu are:

Figure 3.18 Main menu of the REBWIN operator program


3-39

File

The menu item “File” permits databases to be opened and savedand a database to be uploaded from the protection or down-loaded to it.

View

The menu item “View” contains menu items for viewing the plantdiagram, the measurements of each protection zone, inputs andoutputs, switchgear statuses, the event list and any tripping thathas taken place.

Settings

The menu item “Settings” provides facility for setting the systemparameters and the operating values for the various protectionfunctions (busbar, breaker failure, time-overcurrent, end zone etc.).

Configuration

The menu item “Configuration” concerns the layout of the pri-mary system, i.e. the activation/deactivation (masking/ unmask-ing) of circuit-breakers, isolators, c.t’s and v.t’s, the configurationof inputs, outputs and the disturbance recorder and the planningof maintenance.

Testing

The menu item “Test” is for enabling/disabling either the test orinstallation mode.

Tools

Functions for producing reports, changing passwords and settingthe system time are available under the menu item “Tools”.

Clicking on a menu item opens a dialogue for entering the con-figuration data for the particular item or reading the values of therespective parameters.


3-40

Figure 3.19 Example of settings dialogue for busbar protection

For further details, see Section 4 “REBWIN PC operator program”and Section 5 “Configuration and setting”.

3.3. Operating principle of the busbar protection

The REB500 busbar protection detects and trips phase andearth faults in MV, HV and EHV power systems.

The main demands the busbar protection has to fulfil are:

• fast and discriminative isolation of the faulted section of bus-bar

• high through-fault stability

3.3.1. Busbar sections and protection zones

3.3.1.1. Busbar configurations

The REB500 busbar protection is applicable to virtually all bus-bar configurations. A few of the most common examples of themany possible busbar configurations are given below:


3-41

I

Figure 3.20 Single busbars

III

Figure 3.21 Double busbars and bus-tie breaker

Bypass

III

Figure 3.22 Double busbars and bypass busbar


3-42

II

I

Figure 3.23 1½ breaker scheme

Figure 3.24 Ring busbars

3.3.1.2. Division into protection zones

The REB500 busbar protection protects all busbar configura-tions from single busbars to quadruple busbars and a bypassbusbar, 1½ breaker schemes and ring main busbars. The maxi-mum capacity is 59 bay units (a bay unit per feeder or in thecase of a bus-tie breaker a bay unit per set of c.t’s; longitudinalisolators can be equipped either with bay units of their own orthey can jointly use and existing bay unit). Faults on up to 32busbar sections (protection zones) can be discriminatively de-tected and tripped.

3.3.2. Measuring principle

The busbar protection (BBP) operates according to the principleof a combined differential current measurement with operationand restraint features and a phase comparison function. In ahealthy condition, all the current flowing towards a busbar sec-tion must leave it again.

The busbar protection scheme is based on a measurement algo-rithm which compares the amplitudes of the feeder currents and


3-43

derives a restraint criterion. The algorithm is executed inde-pendently for every protection zone and phase. In addition toamplitude comparison, their phase relationship is also comparedas a second criterion (see Section 3.3.2.2. “Phase comparison”).The neutral current has to be separately monitored in powersystems with impedance grounding (see Section 3.3.2.4. “Neu-tral current measurement”).

Yes

Phase L1measuring system

No fault detected

Internal fault on phase L1

Inclusion of neutral current permissible?

No Restrained amplitude comparison

Internal fault?

Phase comparison

Internal fault?

No

Restrained amplitude comparison

Internal fault?

Phase comparison

Internal fault?


Internal ground fault

Intertripping command


Neutral current measuring system(impedance grounded systems)

NoRestrained amplitude comparison

Internal fault?

Restrained amplitude comparison

Internal fault?

Phase comparison

Internal fault?

Phase comparison

Internal fault?

No fault detected

No fault detected



No fault detected

NoNoNo

NoNoNo

Yes Yes

Yes Yes Yes

Yes

Yes

Yes

Figure 3.25 REB500 protection functionsThe logic linking the protection functions (Figure 3.25 “REB500protection functions”) shows that the REB500 protection canonly trip when both protection functions (restrained amplitudeand phase comparisons) detect a fault on the same busbar sec-tion and phase. If the user wishes, the neutral current is alsoevaluated independently of the phase measurements in impe-dance grounded systems.


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3.3.2.1. Restrained amplitude comparison algorithm

The restrained amplitude comparison function is basically a dif-ferential current measurement with the sum of all the currentamplitudes Irstnt acting in a restraining sense.

Amplitude comparison

The differential current Idiff is the geometric sum of all the cur-rents flowing towards and away from the busbar.

The data transfer capacity from the bay units to the central unitis not unlimited and for this reason, only the real and apparentcomponents of the fundamental are transferred to the centralunit for evaluation. Thus only the complex components of thefundamental are processed by the digital protection REB500, theharmonics being suppressed by Fourier filters.

The differential current Idiff is calculated from the fundamentalcomponents of the currents ( ) ( )Re ImI j ILn Ln+ ⋅ conducted by thefeeders and the bus-tie breakers.

( )[ ] ( )[ ]==

⋅+=N

1nLn

N

1nLndiff IImjIReI per protection zone

Restraint current

The stability factor k is derived from the restraint current Irstntwhich is the sum of the currents of the various feeders. The fol-lowing is an example for the determination of the restraint cur-rent Irstnt for phase L∈L1, L2 L3:

( ) ( )=

⋅+=N

1nLnLnrstnt IImjIReI per protection zone

The stability factor k thus becomes:

( )[ ] ( )[ ]

( )=

==

+

⋅+== N

1nLnLn

N

1nLn

N

1nLn

rstnt

diff

IIm)IRe(

IImjIRe

IIk per protection zone

where

k stability factor

ILn fundamental component after the Fourier filter inphase L of feeder n

N total number of feeders and bus-tie breakers per pro-tection zone


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The scheme detects and internal fault on the busbar when thestability factor k exceeds the setting (typically 0.80) and the dif-ferential current Idiff is greater than the setting for the restraintcurrent IKmin. The differential current in normal operation or dur-ing a through-fault is close to zero. By including the restraint cur-rent in the denominator the range for the stability factor k be-comes 0 ≤ k ≤ 1.

Simplified example:

I1 = 5 kA I2 = 5 kA

I3 = 10 kA

( )[ ] ( )[ ]

( )=

==

+

⋅+== N

1nLnLn

N

1nLn

N

1nLn

rstnt

diff

IIm)IRe(

IImjIRe

IIk

01055

1055k =

−++−+

=

Figure 3.26 Through-fault

I1 = 5 kA I2 = 5 kA I3 = 0 kA

( )[ ] ( )[ ]

( )=

==

+

⋅+== N

1nLnLn

N

1nLn

N

1nLn

rstnt

diff

IIm)IRe(

IImjIRe

IIk

1055

055k =

++++

=

Figure 3.27 Internal fault

I1 = 5 kA I2 = 5 kA

I3 = -2 kA

( )[ ] ( )[ ]

( )=

==

+

⋅+== N

1nLnLn

N

1nLn

N

1nLn

rstnt

diff

IIm)IRe(

IImjIRe

IIk

67.0255

255k =

−++−+

=

I1 + I2

Idiff

I3

Figure 3.28 Through-fault with c.t. saturationEvaluation by the restrained amplitude comparison function isdivided between the bay units and the central unit. Every bayunit continuously monitors the currents of its feeder, performsthe Fourier filter function and transfers the corresponding valuesto the central unit at intervals of 8 ms. The central unit adds the


3-46

currents received from the bay units and monitors the resultingdifferential current.

High through-fault currents can cause one or more c.t’s to satu-rate and could give rise to a false differential current which, if noprecautions were taken against it, might be interpreted as aninternal fault. In REB500, the current signals are pre-processedby a “maximum prolongation” function patented by the supplier,and this maintains protection stability and discrimination in thepresence of c.t. saturation.

The principle involves detecting and holding the maximum am-plitude in the sampling window. The phase-angle and amplitudeof the fundamental component at the output of the Fourier filterare corrected by the maximal prolongation function such that aclose approximation to the phase and amplitude of the unsatu-rated fundamental is obtained.

t

0

40 ms10 20 30-40

-20

20

40

60 IN

0ta th

to

I

Undistorted current signal

Distorted current signal

Corrected current signal

Undistorted current signal (main c.t. primary)

Distorted current signal (main c.t. secondary)

Figure 3.29 Maximum prolongation to compensate c.t. satura-tion

The time t0 is the interval between the zero-crossing precedingthe maximum amplitude and the end of the prolongation of themaximum amplitude. This time is 12.5 ms in a 50 Hz system and10.4 ms in a 60 Hz system. The rise time between the precedingzero-crossing and the maximum amplitude sample is designatedta. The difference between t0 and ta is the time th and equalshow long the maximum amplitude is prolonged. The higher ta,the shorter the maximum amplitude is prolonged.


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3.3.2.2. Phase comparison

High stability in the presence of severe c.t. saturation is charac-teristic of busbar protection schemes that compare the phase-angles of the currents. This still applies when re-energising asystem and adding to the residual flux stored in the c.t. cores. Itis for this reason that phase comparison was chosen as theprinciple for the second criterion of the REB500 busbar protec-tion system.

The function compares the phase-angles of the fundamentalcomponents of the feeder currents.

Diagram of busbar

Operating characteristic

Phas

e-sh

ift ∆

ϕ

0°

74°

180°

1 2Case

operates

internal fault

Case 1: external fault = 139°∆ϕ

Im

Re

Case 2: internal fault = 40°∆ϕIm

Re

I1 I2 I2

I1

ϕ = 139°12

ϕ = 40°12

I1

I2

max∆ϕ = 74°

Figure 3.30 Principle of the phase comparison functionAssuming an internal fault on a section of a busbar, the currentsof all the feeders connected to it have the same phase-angle. Innormal operation or during a through-fault, on the other hand, atleast one of the currents is 180° out of phase with the others.The phase comparison function therefore compares the phase-angles of all the currents of each phase individually for eachzone of protection. The phase difference for tripping is 0° to 74°,i.e. if the phase-angles of all the feeder currents of a protectionzone lie within a band of 74°, the phase comparison function de-cides that there is an internal fault. The pick-up angle ∆ϕmax of74° is a fixed setting.


3-48

For proper operation, it is necessary to exclude feeders con-ducting very little or no current from the comparison to preventnoise generated by them or balancing currents during a faultfrom disturbing the measurement. A minimum current is there-fore determined when engineering the scheme for a particularapplication below which a feeder is excluded from the phasecomparison. Typical settings are 0.8 IN for the phase currentsand 0.25 IN for the neutral current.

Tripping

Tripping only takes place if the differential current and the stabil-ity factor are both above their pick-up settings and the phasedifference between the currents is less than setting.

Idiff > Idiff set

setrestr

diff kIIk >=

∆ϕ < ∆ϕset

Trip

Figure 3.31 Busbar protection tripping logic

3.3.2.3. Differential current alarm

The differential current alarm is activated on the HMI of the cen-tral unit and signalled externally by the binary output“41815_Diff. current alarm”, if a differential current lasting longerthan the corresponding timer setting is detected. The alarm onlyresets when the spurious differential current has disappeared.

According to the user’s wishes, the differential current alarm isconfigured to either completely block the protection, only blockthe zone concerned or simply give alarm and the protection re-mains in operation.

Spurious differential currents can occur due to faults in the c.t.secondary circuits (short or open-circuit or reversed polarity).


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3.3.2.4. Neutral current alarm

The operation of the neutral current alarm depends on the dif-ferent methods of grounding a power system:

System grounding Consequences for the protection

Solidly grounded Fault current IKmin to IkmaxAll faults detected by the busbar protection.

Ungrounded Capacitive fault currentGround faults detected by other protection devices.

Impedance grounded Limited ground fault currentGround faults detected by busbar protection (neu-tral current monitor)

Petersen coil Only residual ground fault currentFaults generally not detected, because the fault arcis extinguished.

Table 3.7 Ground fault current for the different methods ofpower system grounding

Note: The neutral current alarm is only enabled for impedancegrounded power systems and at the user’s specific request (seeSection 11).


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3.3.2.5. Operating times

Depending on the ratio between the actual differential current Idiffand the setting IKmin, the system trips 20 to 28 ms after the inci-dence of a fault. The curve below shows typical operating timesfor different values of the quotient Idiff/IKmin.

Operating time

max. 28 ms

min. 20 ms

minK

diff

II

Figure 3.32 Typical operating times of the REB500 busbarprotection system

The total operating time is determined by a number of individualoperating times as listed in the table below:

Time t Diagram Definition Time

t1 Fault detection time (Idiff/IKmin = 10) 3 ms

t2 Polling dialogue (1 bus cycle) 0-(8) ms

t3 Bay unit preparations 4 ms

t4 Transfer and processing by the CU 8 ms

t5 Trip signal enable in the BU 1.5 ms

t6 Operation of the protection trip relay 5 ms

t7 Safety margin 0.4 ms

tΣΣΣΣ Total operating time 21.9 ms

Table 3.8 Times contributing to the total operating timeThe individual functions contributing to the total operating timeare partly in the central unit and partly in the bay units. A graphicrepresentation of the operating time is given below. Note that thetime from 21.9 to 29.9 ms is caused by the fact that the centralunit processes cyclically, i.e. if a fault occurs at the end of a


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processing cycle, the waiting time until the start of the next proc-essing cycle is only short, but if it occurs near the beginning of acycle, the waiting time until it can be processed is relatively long.

t =3 ms1

t =8 ms2

t =4 ms3

t =8 ms4

t =1.5 ms5

t =5 ms6

t =0.4 ms7

t =21.9 - 29.9 ms

4 ms 4 ms

Bay unit

Central unit

Start of fault Protection trip

IDiff

IKmin=10

Σ

HEST 005033 C

Figure 3.33 Contributions of the central and bay units to thetotal operating time

3.3.2.6. Enabling the tripping command

As mentioned previously, the principle of the busbar protection isbased on the measurement of three criteria: current amplitudecomparison, a stability factor and a directional (phase) compari-son. Tripping of the zone concerned can only take place whenall three criteria are fulfilled at the same time.

In exceptional cases, it may be necessary to add an enablingcriterion before tripping is permitted. Two examples of suchsituations are:

• The specification for the station stipulates that only those cir-cuit-breakers of a zone should be tripped that are actuallyconducting current and those that are not contributing to thefault current should not.This response can be obtained by adding an overcurrentenabling criterion to each of the bay units (see Section 11.6.3“Overcurrent check feature for enabling the tripping com-mand”).

In stations where the maximum load current of certain feedersexceeds the minimum fault current (e.g. ground faults in imped-ance grounded systems), a spurious differential current due to


3-52

an open-circuit c.t. can occur which is higher than the amplitudecomparison setting.In this case, the internal REB500 low voltage check feature oran external input (external undervoltage relay) can be configuredas an enabling criterion for each zone (see Section 11.6.1 “Low-voltage check for enabling tripping” and also the following para-graph “External enabling signal”).

External enabling signal

An external enabling signal can be configured for either a bayunit or a busbar zone. The signals “11605_External release Trip”and “31805_External release BB zone” are provided for this pur-pose for the bay unit and bus zone respectively (see Section3.3.3. “ITT (intertripping)”).

3.3.3. ITT (intertripping)

REB500 includes an intertripping function which performs twomain tasks:

• Maintains an image of the busbar layout and assigns theanalogue measurements to the protection zones:

- Slow part (approx. every 128 ms)

General assignment of feeders to protection zones (ac-cording to the isolator positions)

The connection of protection zones via isolators anddetection of the circuit-breaker positions

- Fast part (approx. every 8 ms)

Detection of advanced circuit-breaker closing com-mands (bus-tie breakers, end zone faults)

Assignment of analogue measurements to protectionzones

• Tripping logic (generation of tripping commands for eachzone for the following protection functions):

- External trip

- Busbar protection (of the faulted zone)

- End zone protection (the protection zone in which the endzone fault is detected)

- Breaker failure protection (the protection zone in whichthe defective circuit-breaker is detected)


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- Tripping enabling signals (external enabling signals andlow-voltage check function)

3.3.3.1. Busbar image

The busbar image is based on a topological principle, i.e.REB500 only includes topological items that are necessary fromthe point of view of protection. It starts with a busbar section andchecks all its electrical connections and constructs a protectionzone bounded by the following items:

• circuit-breaker/c.t. pairs

• bus-tie breakers

• c.t./feeder pairs

• feeder

This procedure is repeated until all the section of the busbarhave been determined.

Topological items are:

• busbars

• isolators and longitudinal isolators

• circuit-breakers

• c.t’s

• bus-tie breaker c.t’s

• bus-tie breakers

• feeders

• connections


3-54

Figure 3.34 Example of double busbars with longitudinal iso-lators

In order to determine in which section of the busbars a differen-tial current has occurred, the protection has to have an image ofthe actual busbar configuration at the time. Therefore auxiliarycontacts on the isolators and bus-tie breakers signal to the pro-tection whether the respective item is open or closed. Using aconfiguration tool when engineering the system, a database filecalled the configuration file is created in which the layout of thespecific station is stored.


3-55

Figure 3.35 Station diagram used by REB500The following complex example illustrates the possibilities andadvantages of busbar images and intertripping logics based onthe topological principle.

Example for a 1½ breaker scheme

Q01 Q02

Q03

T1 T2

T3

ab

c

ab

c

Feeder 1 Feeder 2

A D

B C

Diameter

c

HEST 005035 C

Figure 3.36 Protection zones in 1½ breaker scheme

T zone configurations

ab

c

ab

c

ab

cT5 Q6

Variante 1 Variante 2 Variante 3

Figure 3.37 Alternative T zone configurations


3-56

The busbar protection always detects faults in the two mainzones A and D, but if REB500 is configured solely as a busbarprotection, its busbar image will not model the T zones andlooks upon the scheme as two single busbars (A and D). The Tzone configurations of Versions 2 and 3 are, however, an ex-ception:Version 2:

Assuming there is a c.t. T5 on the line side, which is, togetherwith the centre c.t. T3, included in the busbar image (i.e. con-nected to bay units), the busbar protection protects the T zonediscriminatively.

Version 3:

Providing the isolator Q6 on the line side and the centre c.t. T3are included in the REB500 busbar image (i.e. connected to bayunits), the T zones are protected as long as the isolator Q6 isopen.REB500 automatically disables the measurement of the respec-tive T zone when the isolator Q6 is closed, because the feedercurrent is not detected by the busbar protection and therefore nomeasurement can be made for the zone.This version is an ideal complement for a feeder protectionscheme. When the isolator Q6 is closed, the feeder protection(line or transformer protection) also protects the T zone, andwhen the isolator Q6 is open, the T zone is protected by REB500.

If REB500 also performs other protection functions such asbreaker failure or end zone protection in addition to busbar pro-tection, then the entire 1½ breaker scheme has to be modelledby the busbar image regardless of T zone configuration (Ver-sions 1 to 3). Even in cases when the busbar protection cannotprotect the T zones (Version 1 and Version 3 with Q6 closed),they are included in the intertripping logics of the breaker failureand end zone protection functions.The remote tripping signals (tripping signals to the remote endsof feeders 1 and 2) are transferred via the T zone intertrippinglogics (21115_REMOTE TRIP). Conversely, tripping signals re-ceived from the remote stations (feeders 1 and 2) go to the bayunits of the respective feeders (11105_External TRIP). An active“External TRIP” input causes REB500 to trip both circuit-break-ers limiting the T zone and internally enables the breaker failurefunction for the T zone.

The number of bay units required can be determined by a simplerule of thumb:


3-57

n bay units = whichever is the greater of the total number ofcircuit-breakers or the total number of c.t’s included in thebusbar image.

The single-line diagram of a complete 1½ breaker scheme ismodelled in REB500 as follows:

Single-line diagram

Figure 3.38 Typical single-line diagram of a complete 1½breaker scheme in REB500

Figure 3.39 shows the assignment of REB500 bay units to thebays of a 1½ breaker scheme. Where a feeder bay includes ac.t. that is used for the REB500 measurement (Version 2), eachof the two feeders must has to have its own bay unit.


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Feeder 2

Single-line diagram

Feeder 1

Figure 3.39 Assignment of bay units in a 1½ breaker scheme

3.3.3.2. Supervising isolator positions

Auxiliary contacts on the isolators and bus-tie breakers indicatethe OPEN and CLOSED positions. They apply a voltage to theirrespective inputs on the busbar protection.The busbar replica is refreshed every 128 ms.

An algorithm supervises the steady-state statuses of the isolatorsignal voltages and checks that only one of the two for eachisolator is present, i.e. either the voltage from the CLOSEDcontact or the voltage from the OPEN contact. Alarm is given ifeither both signals are missing or both are present at the sametime.

Every isolator and bus-tie breaker must have a potentially-freenormally-open and a potentially-free normally-closed contact, theN/O contact signalling that the isolator or bus-tie breaker is“CLOSED” and the N/C contact that it is “OPEN”.

When closing an isolator or bus-tie breaker, the N/O contactmust close a certain time (approx. 0.15 s) before the gap be-tween the main contacts has reduced to the breakdown level.


3-59

When opening an isolator or bus-tie breaker, the N/O contactmust not open before the gap between the main contacts ex-ceeds the breakdown level so that an arc cannot be ignited.Should this not be the case, i.e. the N/O contact signals “NOTCLOSED” before the voltage withstand between the main con-tacts has been established, then on no account may the N/Ccontact signal that the main contact is “OPEN” before the maincontacts reach their voltage withstand.

End position:Isolator/bus-tie breakeropen

Aux. contact must be closed

Isolator/bus-tie breaker closing

N/O aux.contact signallingmain contact CLOSED

Isolator/bus-tie breaker opening

Flashover gap

End position:Isolator/bus-tie breakerclosed

Aux. contact may be closedAux. contact must be open

N/O aux.contact signallingmain contact OPEN

Isolator/bus-tie breakermain contact

HEST 005036 C

Figure 3.40 Switching sequence of isolator/bus-tie breakermain and auxiliary contacts

The protection system checks that only one signal is present(either “CLOSED” or “OPEN”) and gives alarm should this not bethe case. In the event of an isolator alarm, there are two possi-ble blocking modes that can be configured:

• Blocking of the entire protection system

• Discriminative blocking of just the zone concernedDue to the differing operating times of the auxiliary contacts, thesignals applied to the busbar image while an isolator is movingmay be briefly incorrect. The supervision function should nottherefore give alarm while an isolator is in motion and has to bedelayed. The protection system interprets the isolator and bus-tie breaker position signals as follows:


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Isolator/bus-tiebreaker “CLOSED”contact

Isolator/bus-tiebreaker “OPEN”contact

Isolator/bus-tie position inbusbar replica

open open Last position stored+ “Isolator alarm” after delay+ “No switching permitted”

open closed OPEN

closed open CLOSED

closed closed CLOSED+ “Isolator alarm” after delay+ “No switching permitted”

Table 3.9 Interpretation of the isolator/bus-tie breaker auxil-iary contacts by the protection system

After the set time delay, operation of the alarm is signalled onthe local control unit and by the output signal “Isolator alarm”.

If the alarm was generated by an isolator or bus-tie breaker thatat the time designates the limit of a protection zone, the signal“No switching permitted” is also set. This signal is not set, how-ever, if the isolator or bus-tie breaker concerned is not critical fordetermining the limit of a protection zone. Figure 3.41 shows anexample of a bus-tie breaker which can be switched withouttaking special precautions, because all the isolators Q1, Q2,Q10 and Q20 are open and the bus-tie breaker Q0 is not as-signed to a protection zone and therefore of no consequence forthe busbar image.

Q0

Q2 Q1 Q20 Q10

Q11

Q21

Figure 3.41 Bus-tie breaker of no consequence for the busbarimage when all the isolators are open


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“Isolator alarm” and “No switching permitted”

Figure 3.42 shows a timing diagram for the response of the iso-lator alarm and for inhibiting switching. The signal “Isolatoralarm” is reset by applying a signal to the “Reset isolator alarm”input on the central unit and tripping can once again take place.If the “Isolator alarm” signal is not reset, it resets on its own assoon as all the isolators are in valid positions.

The possibility of acknowledging an existing isolator alarm wasincluded for feeders undergoing maintenance (i.e. inactive feed-ers). While a feeder is being maintained, it can occur that thesupply to the auxiliary contacts on the isolators is interrupted andthe appropriate signals are not applied to the REB500 busbarimage. No attention need be paid to the resulting isolator alarmbecause a feeder that is being maintained cannot be assigned toan active protection zone.

Caution: Operating isolators while the “No switching permitted”signal is active is not recommended. On no account may anisolator in the busbar section concerned by operated. Thepositions of the isolators that were valid last are stored and thecurrent of a feeder that was subsequently switched would re-main assigned to the original protection zone. This may cause adifferential current alarm and, if the isolator alarm is not config-ured just to block the protection, also false tripping.

The “No switching permitted” signal is only reset when all theisolators are in valid positions.


3-62

Isolator alarm

Isolator alarmacknowledge

defined undefined defined

Protection blocked(if selected)

No switching permitted

Busbar imagesupervision

Delay

Figure 3.42 Response of the “Isolator alarm” and “No switch-ing permitted” signals

Blocking by the differential current or isolator alarmsWhat happens in the event of a differential or an isolator alarmhas to be determined when engineering the scheme. By appro-priately setting parameters the protection can be disabled or en-abled when an alarm occurs. What is disabled and what enabled can be set independently fordifferential and isolator alarms. The corresponding logics areexplained at the end of this section.The isolator alarm blocks the intertripping logic and thereforeintertripping by the busbar, time-overcurrent and breaker failureprotections etc., is no longer possible.A differential current alarm only blocks the busbar protection; theother protection functions can still initiate intertripping.

Notes on isolators and circuit-breakersIf an isolator or circuit-breaker is not assigned to a binary input(but is included in the REB500 single-line diagram), the protec-tion assumes it to be closed. This only applies to unmaskedbays.In the case of feeders with the c.t’s on the line side of the circuit-breaker, the assignment of the feeder current in the protection isdependent on whether the circuit-breaker is open or not, but ifthe c.t’s are on the busbar side, the position of the circuit-breaker is of no consequence for the busbar protection.In combined busbar and breaker failure protection systems thepositions of the feeder circuit-breakers are not taken into ac-count, but are assumed to be always closed. Their positions andalso the generation of closing commands have to be taken intoaccount, however, in systems including an end zone protection.


3-63

3.3.4. Bus-tie breaker functions

3.3.4.1. Bus-tie breaker

Excluding the bus-tie breaker measurement

The measurement of the current flowing through the bus-tiebreaker has to be excluded from the evaluation in certain situa-tions, e.g. in order to detect and trip a fault between the c.t’s andthe bus-tie breaker when it is open.

The reclaim timer is started when the busbar protection hastripped or the “OPEN” auxiliary contact on the bus-tie breaker isclosed and there is no close command. This ensures that whenthe bus-tie breaker is tripped, any arcing or re-ignition is correctlymeasured by the protection before the busbar image is rear-ranged to take account of the open bus-tie breaker.

The bus-tie breaker is excluded from the measurement after thereclaim time.

In order to be prepared for closing the breaker onto an existingfault (e.g. closed grounding isolator), the bus-tie breaker meas-urement has to be reinstated before the breaker is actuallyclosed. To this end, the bus-tie breaker close command goes tothe busbar protection as well and forces the busbar image intothe configuration as if the bus-tie breaker were already closed.As soon as the breaker is closed, this function is performed bythe “CLOSED” auxiliary contact on the bus-tie breaker. Theclose command to the bus-tie breaker must be maintained untilthe auxiliary contact on the breaker has definitely closed (over-laps with the auxiliary contact that is opening).

The second case when the bus-tie measurement has to be ex-cluded is when the bus-tie breaker connecting two sections ofbusbar is bypassed by isolators. The exclusion in this case isperformed by a logic on the basis of the relative positions of thebus-tie breaker and the corresponding isolators.


3-64

HEST 985033 C

Figure 3.43 Bus-tie breaker bridged by isolatorsThe exclusion of the bus-tie breaker measurement relies on thefact that the positions of the auxiliary contacts reflect the trueposition of the bus-tie breaker. This is not always the case un-less the auxiliary contacts are mechanically coupled to the cir-cuit-breaker.

Bus-tie breaker with one set of c.t’s

HEST 985 001 FL

Bus zone IProtection zone I

Bus-tie breakerC.t’s

Bus zone IIProtection zone II

Figure 3.44 Bus-tie breaker (closed) and one set of c.t’sWhere a bus-tie breaker is equipped with only one set of c.t’s, ithas to be used for the measurement of the bus zones on bothsides of the bus-tie breaker (the c.t’s are assigned to the zonesautomatically when the system is configured).

Faults in bus zone II are tripped selectively and without delay byprotection zone II and faults in bus zone I to the left of the c.t’s inFigure 3.44, i.e. in protection zone I, are tripped selectively andwithout delay by protection zone I.

For a fault between the c.t’s and the bus-tie breaker (i.e. in buszone I), zone II trips first without delay (including the bus-tiebreaker) although zone II is the healthy zone. Zone I trips to fi-nally clear the fault after the reclaim time. The reclaim time mustbe set longer than the maximum tripping time (including arc ex-tinction time) of the bus-tie breaker.


3-65

Cancelling the exclusion of the bus-tie breaker with one setof c.t’sWhen a bus-tie breaker is only equipped with one set of c.t’s, theexclusion of the bus-tie breaker from the measurement appliesfor both zones.Station layouts, however, are possible in which a switchgear bayis sometimes used as a bus-tie breaker and sometimes as afeeder circuit-breaker.

Figure 3.45 Example of a bus-tie breaker that can also beused as a feeder circuit-breaker

Q1, Q0 and Q20 closedQ2 and Q7 open bus-tie breakerQ1 or Q2, Q0 and Q7 closedQ20 open feeder circuit-breakerIn such cases, the exclusion of the bus-tie breaker measurementis selectively disabled for one of the two protection zones whileengineering the system, i.e. the measurement of the bus-tiebreaker remains active.


3-66

Bus-tie breaker with two sets of c.t’s

Bus zone IProtection zone I

Bus-tie breakerC.t’s 1

Bus zone II

Protection zone II

C.t’s 2

HEST 985 002 FL

Figure 3.46 Bus-tie breaker (closed) and two sets of c.t’sIf there are c.t’s on both sides of the bus-tie breaker, they areassigned to the busbar zones as shown in Figure 3.46, i.e. c.t’s2 are the limit of protection zone I and c.t’s 1 the limit of protec-tion zone II. A bay unit is required for each set of c.t’s. It is notabsolutely essential to use both sets of c.t’s and if only one isused, the arrangement is as described above for bus-tie break-ers with one set of c.t’s.

Faults between the sets of c.t’s trip both faulted and healthy buszones without delay.

When the bus-tie breaker is open, the c.t’s are assigned to noneof the zones and the protection zones extend to the bus-tiebreaker. Thus a fault between the c.t’s and the bus-tie breaker isdetected and tripped in the correct zone.

Bus zone IProtection zone I Protection zone II

Bus zone II

Bus-tie breakerC.t’s 1 C.t’s 2

HEST 985 003 FL

Figure 3.47 Bus-tie breaker (open) and two sets of c.t’s


3-67

3.3.5. REB500 system signals

GEN

BBP

BFP

EFP

O/C

CBPD

DR

ITT system, self- supervision, operation

Busbar protection

Options

Principle of the REB500 System Signals

GEN

General Function

DR

Disturbancerecorder

O/C

Time-overcurrentBBP

Busbar Protection

EFP

End ZoneProtection

CBPD

CB PoleDiscrepancy Protection

BFP

Breaker FailureProtection

REB500 System

UV

Low-voltageCheck Feature

UV

HEST 005038 C

Figure 3.48 Principle of the REB500 system signals


3-68

Cap

tion

Dev

ice_

Func

tion

_Inp

ut/O

utpu

t

SYS

BBP

BFP

EFP

OC

DT

DR

CBP

D

UV

11105_External TRIP BU_SYS_E11110_External TRIP BB zone BU_SYS_E11205_Block all BU_SYS_E11210_Block output relays BU_SYS_E11215_Ext. Measurement disturbed BU_BBP_E11505_Close command CB BU_SYS_E11510_Supervision aux. Voltage_1 BU_SYS_E11515_Supervision aux. Voltage_2 BU_SYS_E11520_Supervision aux. Voltage_3 BU_SYS_E11525_Supervision aux. Voltage_4 BU_SYS_E11530_Circuit breaker/isolator position BU_SYS_E11530_Circuit breaker-off BU_SYS_E11530_Circuit breaker-on BU_SYS_E11530_Isolator-off BU_SYS_E11530_Isolator-on BU_SYS_E11605_External release Trip BU_SYS_E11610_External reset BU_SYS_E11615_Inspection_1-Off BU_SYS_E11620_Inspection_1-On BU_SYS_E11625_Inspection_2-Off BU_SYS_E11630_Inspection_2-On BU_SYS_E11635_Inspection_3-Off BU_SYS_E11640_Inspection_3-On BU_SYS_E11645_Inspection_4-Off BU_SYS_E11650_Inspection_4-On BU_SYS_E11655_Maintenance-Off BU_SYS_E11660_Maintenance-On BU_SYS_E1765_General Start DR BU_SYS_E13205_Block BFP BU_BFP_E13605_Trip transferred BU_BFP_E13705_External Start BFP BU_BFP_E13710_Start BFP L1_1 BU_BFP_E13715_Start BFP L1_2 BU_BFP_E13720_Start BFP L2_1 BU_BFP_E13725_Start BFP L2_2 BU_BFP_E13730_Start BFP L3_1 BU_BFP_E13735_Start BFP L3_2 BU_BFP_E13740_Start BFP L1L2L3_1 BU_BFP_E13745_Start BFP L1L2L3_2 BU_BFP_E13750_Start BFP L1L2L3_3 BU_BFP_E13755_Start BFP L1L2L3_4 BU_BFP_E13760_Start BFP L1L2L3_5 BU_BFP_E13765_Start BFP L1L2L3_6 BU_BFP_E14205_Block EFP BU_EFP_E15210_Block OCDT BU_OCDT_E

Table 3.10 REB500 signal list, Part 1


3-69

Cap

tion

Dev

ice_

Func

tion

_Inp

ut/O

utpu

t

SYS

BBP

BFP

EFP

OC

DT

DR

PDF

UV

16705_Start DR_1 BU_DR_E16710_Start DR_2 BU_DR_E16715_Start DR_3 BU_DR_E16720_Start DR_4 BU_DR_E16725_Start DR_5 BU_DR_E16730_Start DR_6 BU_DR_E16735_Start DR_7 BU_DR_E16740_Start DR_8 BU_DR_E16745_Start DR_9 BU_DR_E16750_Start DR_10 BU_DR_E17205_Block PDF BU_PDF_E17210_Start PDF BU_PDF_E18205_Fuse failure superv. UV BU_LV_E21105_EXTERNAL TRIP BU_SYS_A21110_TRIP BU_SYS_A21305_Auslösung BU_SYS_A21305_Trip BU_SYS_A21410_Output relays blocked BU_SYS_A21805_In service BU_SYS_A21810_Loss of supply voltage BU_SYS_A21815_Inspection/maintenance BU_SYS_A21115_Remote TRIP BU_SYS_A22405_BBP blocked BU_SSS_A23105_BFP TRIP BU_BFP_A23110_BFP remote TRIP BU_BFP_A23305_BFP trip t1 BU_BFP_A23310_BFP trip t2 BU_BFP_A23315_BFP trip L1 BU_BFP_A23320_BFP trip L2 BU_BFP_A23325_BFP trip L3 BU_BFP_A23330_Trip transferred BU_BFP_A23335_Trip by BFP BU_BFP_A23405_BFP blocked BU_BFP_A24105_EFP remote TRIP BU_EFP_A24305_EFP trip BU_EFP_A24405_EFP blocked BU_EFP_A25105_OCDT TRIP BU_OCDT_A25305_OCDT Trip BU_OCDT_A25405_OCDT blocked BU_OCDT_A26805_DR ready BU_DR_A26810_DR memory full BU_DR_A26815_DR recording BU_DR_A26820_DR record available BU_DR_A27105_PDF TRIP BU_PDF_A27305_PDF Trip BU_PDF_A27405_PDF blocked BU_PDF_A28805_UV undervoltage BU_LV_A



3-70

Cap

tion

Dev

ice_

Func

tion_

Inpu

t/Out

put

SYS

BBP

BFP

EFP

OC

DT

DR

PDF

UV

31505_Accept bus image alarm CU_SYS_E31805_External release BB zone CU_SYS_E31810_External reset CU_SYS_E31815_Ext. Superv. In service_1 CU_SYS_E31820_Ext. Superv. In service_2 CU_SYS_E31825_Time synchronisation CU_SYS_E31105_External TRIP BB zone CU_SYS_E31205_Block all CU_SYS_E31210_Block output relays CU_SYS_E31215_Block IEC master direction CU_SYS_E32205_Block BBP CU_BBP_E33210_Block BFP CU_BFP_E34215_Block EFP CU_EFP_E35220_Block OCDT CU_OCDT_E36705_General tart DR CU_DR_E37205_Block PDF CU_PDF_E41305_Trip BB zone CU_SYS_A41310_Trip transferred CU_SYS_A41405_All blocked CU_SYS_A4410_Output relays blocked CU_SYS_A41505_Isolator alarm CU_SYS_A41805_Alarm CU_SYS_A41810_In service CU_SYS_A41815_Diff. Current alarm CU_SYS_A41820_Loss of supply voltage CU_SYS_A41825_Inspection/maintenance CU_SYS_A41830_Switch inhibit CU_SYS_A41835_Test generator active CU_SYS_A42305_BBP trip CU_BBP_A42310_BBP trip L0 CU_BBP_A42315_BBP trip L1 CU_BBP_A42320_BBP trip L2 CU_BBP_A42325_BBP trip L3 CU_BBP_A42405_BBP blocked CU_BBP_A43305_BFP trip t1 CU_BFP_A43310_BFP trip t12 CU_BFP_A43405_BFP blocked CU_BFP_A44305_EFP trip CU_EFP_A44405_EFP blocked CU_EFP_A45305_OCDT trip CU_OCDT_A45405_OCDT blocked CU_OCDT_A45805_OCDT start CU_OCDT_A47305_PDF trip CU_PDF_A47405_PDF blocked CU_PDF_A48805_UV undervoltage CU_LV_A


Note: A complete list of all the signals and descriptions of theirfunctions is included in Section 12 “Appendices”.


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3.3.6. REB500 blocking schemeSome central and bay unit input signals can directly influenceoutput signals. The REB500 blocking scheme is illustrated in thefollowing diagram:

17205_Block PDF

27405_PDF blocked

27105_PDF TRIPPDF

HEST 985017 C

33210_Block BFP34215_Block EFP

35220_Block OCDT

32205_Block BBP

31205_Block all

11205_Block all

11105_External TRIP

14205_Block EFP

15210_Block OCDT

13205_Block BFP

23405_BFP blocked

23335_Trip by BFP

23105_BFP Trip23110_BFP remote TRIP

24405_EFP blocked

24105_EFP remote TRIP

25405_OCDT blocked

25105_OCDT TRIP

22405_BBP blocked

21110_TRIP

21105_EXTERNAL TRIP

BFP

EFP

OCDT

BBP

BBP ITT

curr

ents

inte

rtrip

ping

I > Imin

Central Unit

Bay Unit

Figure 3.49 Blocking signals

Note: When signal 31210_Block output relays is active, thestatuses of the protection function outputs remain fixed.


3-72

Legend for Figure 3.49 “Blocking signals”:1) The default value is “1” if the input or the function has not

been configured yet.2) The output is blocked when the signal “31210_Block output

relays” is active and signal 2) was configured using REBWINto block.

3) Blocked by either the isolator or differential current alarms(providing they were correspondingly configured usingREBWIN).

4) Protection function deactivated.5) Transfer tripping signal issued when the c.t’s are on the line

side.Busbar intertripped when the c.t’s are on the busbar side.

6) Detected automatically be the software, e.g. when the cir-cuit-breaker is bypassed.

The influences of input signals on outputs are given in Figure3.50 “Central unit blocking scheme” and Figure 3.51 “Bay unitblocking scheme”.

Legend for Figure 3.50 and Figure 3.51:

B Signal does not change providing it has been configured to block.

E Signal does not change.

F Signal enable (interlocking of enabling and tripping signals.

K Blocking providing this was configured via REBWIN.

M Signal (indication)

P Partial blocking, i.e. The busbar protection function does not generate signals or tripping commands.Blocking has no influence on other functions (BFP, EFP) that act on this output.

S The signal is set.

Z The signal is either reset and blocked or just blockedproviding it was not set at the time of blocking.


3-73

Blocking inputs Alarms EnableBU CU CU BU CU CU

1120

5_Bl

ock

all

1121

0_Bl

ock

outp

ut re

lays

1220

5_Bl

ock

BBP

1320

5_Bl

ock

BFP

1420

5_Bl

ock

EFP

1521

0_Bl

ock

OC

DT

1720

5_Bl

ock

PDF

3120

5_Bl

ock

all

3121

0_Bl

ock

outp

ut re

lays

3220

5_Bl

ock

BBP

3321

0_Bl

ock

BFP

3421

5_Bl

ock

EFP

3522

0_Bl

ock

OC

DT

3720

5_Bl

ock

PDF

4150

5_Is

olat

or a

larm

4181

5_D

iff. c

urre

nt a

larm

1160

5_Ex

tern

al re

leas

e Tr

ip

3180

5_Ex

tern

al re

leas

e BB

zon

e

E B P Z F 41305_Trip BB zone

B 41310_Trip transferred

S B 41405_All blocked

B 41410_Output relays blocked

B S 41505_Isolator alarm

B 41805_Alarm

B 41810_In service

E B E S 41815_Diff. current alarm

B 41825_Inspection/maintenance

B S 41830_Switch inhibit

B 41835_Test generator active

E B E F 42305_BBP trip

E B E F 42310_Trip L0




S B S K K 42405_BBP blocked

Z B Z F 43305_BFP Trip t1

Z B Z F 43310_BFP Trip t2

S S B S F 43405_BFP blocked

Z B Z F 44305_EFP Trip

S S B S F 44405_EFP blocked

Z B Z F 45305_OCDT Trip

S S B S F 45405_OCDT blocked

Z B Z F 45805_OCDT start

Z B Z F 47305_PDF trip

S S B S F 47405_PDF blocked

B 48805_UV undervoltage

Input Output

Figure 3.50 Central unit blocking scheme


3-74

Blocking inputs Alarms EnableBU CU CU BU CU BU

1120

5_Bl

ock

all

1121

0_Bl

ock

outp

ut re

lays

1220

5_Bl

ock

BBP

1320

5_Bl

ock

BFP

1420

5_Bl

ock

EFP

1521

0_Bl

ock

OC

DT

1720

5_Bl

ock

PDF

3120

5_Bl

ock

all

3121

0_Bl

ock

outp

ut re

lays

3220

5_Bl

ock

BBP

3321

0_Bl

ock

BFP

3421

5_Bl

ock

EFP

3522

0_Bl

ock

OC

DT

3720

5_Bl

ock

PDF

4150

5_Is

olat

or a

larm

4181

5_D

iff. c

urre

nt a

larm

1160

5_Ex

tern

al re

leas

e Tr

ip

3180

5_Ex

tern

al re

leas

e BB

zon

e

Z B Z B 21105_EXTERNAL TRIP

Z B Z B P P F Z 21110_TRIP

Z B Z B P Z P F Z 21115_Remote TRIP

Z B Z B P P F Z 21305_Trip

S B S B 21405_All blocked

S S 21410_Output relays blocked

B B 21805_In service

B B 21815_Inspection/maintenance

B S B S Z 22405_BBP blocked

Z B Z Z B Z 23105_BFP TRIP

Z B Z Z B Z 23110_BFP remote TRIP

Z B Z Z B Z 23305_BFP trip t1

Z B Z Z B Z 23310_BFP trip t2

Z B Z Z B Z 23315_BFP trip L1



B B 23330_Trip transferred

Z B Z Z B Z 23335_Trip by BFP

S B S S B S 23405_BFP blocked

Z B Z Z B Z 24105_EFP remote TRIP

Z B Z Z B Z 24305_EFP Trip

S B S S B S 24405_EFP blocked

Z B Z Z B Z 25105_OCDT TRIP

Z B Z Z B Z 25305_OCDT trip

S B S S B S 25405_OCDT blocked

B B 26805_DR ready

B B 26810_DR memory full

B B 26815_DR recording

B B 26820_DR record available

Z B Z Z B Z 27105_PDF TRIP

Z B Z Z B Z 27305_PDF trip

S B S S B Z 27405_PDF blocked

B B 28805_UV undervoltage

Input Output

Figure 3.51 Bay unit blocking scheme


3-75

3.4. Ancillary REB500 functions

3.4.1. Ancillary function descriptions

3.4.1.1. Event memory

The busbar protection includes an event memory for each indi-vidual unit (central unit and bay units) in which changes in thestatuses of binary signal are recorded. The event memorieshave a capacity for 100 events in bay units and 1000 events inthe central unit. The user can select whether the oldest eventshould be overwritten (ring register) or no further events re-corded when the memory is full.

A time stamp (date and time with an accuracy of 1 ms), a textdefined using the operator program and a status (set or reset)are attached to every event. Individual texts can be entered foreach status.

Generally, one event is configured for every input and output,but events can also be assigned to opto-coupler inputs or relayoutputs.

When a PC running the REBWIN operator program is con-nected, the events can be uploaded from the protection to thePC. The events stored in the central unit can only be read whenconnected to the central unit and the events stored in bay unitswhen connected to either the central unit or the respective bayunit.Events that are no longer needed in the PC can be deleted ei-ther individually or collectively in marked groups.

3.4.1.2. Test mode

Provision is made in the REBWIN operator program for switch-ing the protection to the test mode. The test tool includes func-tions for setting up certain protection operating conditions formaintenance and commissioning purposes. For example, certainstatuses can be impressed on the inputs and outputs (i.e. theycan be set and reset via the operator program). This enables theoutput relays and the wiring to be checked or the busbar imageto be changed to a different configuration.

The tripping relays (excepting “42405_BBP blocked”, “41835_Testgenerator active” and “41810_In service”) are automatically blockedwhen the test mode is activated, i.e. changes made to any out-put relays have no effect on the primary system. The operatorprogram also permits the remaining output signals to be


3-76

blocked, all outputs to be enabled again and the changes madein the test mode to be cancelled.

If a bay unit is switched off and back on again while it is in thetest mode, the test mode is no longer active, i.e. the outputs areno longer blocked.

3.4.1.3. Installation mode

Provision is made in the operator program for switching the pro-tection to the installation mode. This is necessary for setting upa new protection system.

3.4.1.4. Masking and unmasking devices

Both individual items of plant (circuit-breakers, isolators or c.t’s)and complete bays can be masked or unmasked (activated ordeactivated).

When masked, they can be set to the status “Masked open” or“Masked closed”.

Feeder 1 Feeder 3 Feeder 2 Bus-tie breaker

Figure 3.52 Example of engineering future development inadvance and provisionally masking the corre-sponding items of plant

Masking individual items of plant:

Bus-tie breaker Q2: Masked open

Q10 Masked open

Q1 Masked bypassed

Q20 Masked bypassed

Q11 Masked bypassed

Q21 Masked bypassed


3-77

Masked bays:Feeder 2: Masked all items openA defective bay or bay unit that is removed from operation canalso be masked in the configuration.Once an engineered and masked bay has actually been builtand commissioned, it has to be unmasked in the protection us-ing the operator program. Every time an item is masked or un-masked, the system database changes and therefore the one inthe protection has to be deleted and the changed one down-loaded to it. The system then has to be started in the installationmode.

Caution: Masking items of plant or complete bays influencesthe REB500 busbar image. Always check after making suchchanges that the REB500 busbar image agrees with the actualstatus of the primary system.It is advisable to consult the supplier before carrying outchanges of this kind.

3.4.1.5. Inspection and maintenanceDuring the routine inspection of a bay, the protection and controldevices and the local protection functions in the REB500 bayunit are also generally checked. Opening the isolators of a bayundergoing maintenance avoids any risk of test trips in the bayfrom intertripping other bay units or an injection current from af-fecting the differential current measurement of the busbar pro-tection.It may also be the case that the bay under test is not generatingany isolator position signals or the signals are disconnected be-cause engineers are working on them. To prevent REB500 fromoperating with an incorrect busbar image in such situations, pro-vision is made for applying a maintenance signal to a bay unitwhich enables one or several isolators or bus-tie breakers to beset to “OPEN”.When all the isolators belonging to a bay are set to “OPEN”, thebay current is not assigned to a protection zone and the currentof the corresponding feeder is not included when the busbarprotection algorithm is executed.


3-78

A REB500 bay unit has four binary inputs for controlling the in-spection mode. These are assigned when engineering the sys-tem to particular isolators or bus-tie breakers.When a inspection input is set, the output signals “21815_Mainte-nance” on the bay unit concerned and “41825_Maintenance” onthe central unit signal the maintenance status.

Caution: The maintenance input on a bay unit may only be ac-tivated after the bay has been completely isolated from the pri-mary system, i.e. the respective isolators are in the “OPEN” po-sition.The use of a key-switch in series with the maintenance signal isrecommended.

The input signal “11660_Maintenance-On” prevents the isolatorpositions from changing, signals the status to the central unitand suppresses the “Isolator alarm” and “No switching permit-ted” signals. The protection uses the last set of valid isolator po-sitions and remains active. A busbar protection trip to the circuit-breaker concerned will still trip it in spite of it being in the main-tenance mode.

Feeder

Figure 3.53 Bay configuration when a maintenance signal isbeing applied

The REB500 maintenance signal forces isolators Q1, Q2, Q0and Q6 into the “OPEN” position, but keeps isolator Q7 closedwhile the bay is being maintained to supply the feeder via anauxiliary busbar.


3-79

Caution: If the bay unit is switched off or reset in this situation,the information pertaining to the isolator positions is lost and theactual positions are used when it starts up again.This is signalled by the isolator alarm until the maintenance sig-nal is removed. Thus when the maintenance signal is active, theisolator alarm means that the isolator positions may havechanged.

3.4.1.6. Time synchronisation

The clocks in the various units are synchronised by what is re-ferred to as “minute impulse”. The corresponding impulse can beconfigured on the BIO of the central unit as a binary input.

Each minute impulse (“31825_Time synchronization” signal) in-crements the time by a minute. The accuracy of the time func-tion is not monitored. Should the impulses fail, the internal clockcontinues to run. When the impulses are restored, however, thefirst impulse increments the time as it was prior to the failure ofthe impulses by one minute. This means that the internal timecan jump backwards. The time therefore has to be readjustedafter a failure.

On the other hand, this system permits, for example, the changefrom standard to summer time to be made by controlling the timesynchronisation function, 60 impulses adjusting the clocks byone hour.

Setting the time

The time is set using REBWIN. The first minute impulse afteradjustment rounds the time to the next full minute.

ExampleTime set at: 12 h 37 min 13 sTime at the next impulse: 12 h 38 min 00 s

The time can be set at any time using REBWIN.

The time between two setting impulses must be at least onesecond and their pulsewidth at least 20 ms for them to be regis-tered as two impulses.

The system only supports minute impulses.

If an interbay bus interface (LON or IEC 60870-5-103) is in use,the master (SCS/SMS) takes over the job of synchronising the


3-80

clocks in the bay units via the bus (see Section 11.8. “Interbaybus (IBB) connection”).

3.4.1.7. Options

All the bay units in the standard version of REB500 include adisturbance recorder which records the current measurementsand up to 32 binary inputs and outputs during a period of 1.5 s.

The central unit and optionally the bay units can be fitted with alocal control unit (HMI) with LED’s for alarm, tripping andstandby, a four-line text LCD and buttons for communicatingwith the system. For greater convenience and flexibility, a PCrunning the REBWIN operator program can be connected to anoptical interface.

The current measurements can also be used for other protectionfunctions. Optional ancillaries for the REB500 system are abreaker failure protection (BFP), an end zone fault protection(EFP), a time-overcurrent function (OCDT) and a circuit-breakerpole discrimination function (PDF). There are also additionaldisturbance recorder functions (including power system voltagemeasurement) which are optionally available.

It is possible to apply the REB500 system without the basic bus-bar protection function in cases where only the ancillary func-tions are required (e.g. an independent breaker failure or endzone fault protection).

Details of the various options are given in Section 11.

3.5. Technical specification

3.5.1. Data Sheet

The technical data and wiring diagrams are contained in theData Sheet for the REB500 system included at the end of thissection.

Page 1

Main features • High reliability due to two independent measurement criteria:

- stabilized differential current algorithm

- directional current comparison algorithm

• Phase-by-phase measurement

• Reduced c.t. performance requirements

• High through-fault stability even in case of c.t. saturation

• Full solid-state busbar replica

• No switching of c.t. circuits and therefore no check zone required

• One version for c.t’s of 1 and 5 A

• One version for all battery voltages between 48 and 250 V

• Short tripping time regardless of the size or configuration of the station

• Centralized layout: Installation of hardware in one or several cubicles

• Distributed layout: Bay units distributed and - in the case of location close to the feeders - with short connections to c.t's, isolators, circuit breakers, etc.

• Connections between bay units and central unit by fibre optic cables - maximum per-missible length 1200 m - for distributed and centralized layout

• Fibre optic connections mean interference-proof data transfer even close to HV power cables

• Replacement of existing busbar protection schemes can be accomplished without restrictions (centralized layout). In the case of substation extensions e.g. by a mixture of centralized and distributed layout.

• Easily extensible

• Remote and external user-friendly human machine interface

• Full digital signal processing

• Self-supervision

• Integrated event recording

• Integrated disturbance recording for power system currents

• A minimum of spare parts needed due to standardization and a low number of vary-ing units

Options • Breaker failure protection

• End-fault protection

• Definite time-overcurrent protection

• Disturbance recording for power system voltages

• Separate I0 measurement for impedance-grounded networks

• Communication with substation monitoring and control system (LON/IEC)

• Internal user-friendly human machine inter-face with display

• Redundant power supply for central units and/or bay units

Numerical busbar and breaker-failure protection

REB500

1MRB520256-Ben

Issued: March 2000Changed since: October 1999

Data subject to change without notice

REB500 busbar protection for distributed installation

ABB Power Automation REB5001MRB520256-Ben

Page 2


Application The numerical busbar protection REB500 is designed for the high-speed, selective protec-tion of MV, HV and EHV busbar installations at a rated frequency of 50 or 60 Hz. The structure of both hardware and software is modular enabling the protection to be easily configured to suit the layout of the primary system.

The flexibility of the system enables all con-figurations of busbars from single busbars to quadruple busbars with transfer buses, ring busbars and 1½ breaker schemes to be pro-tected. The capacity is sufficient for up to 59 feeders (bay units) and a total of 32 busbar zones.

The numerical busbar protection REB500 de-tects all phase and ground faults in solidly grounded and resistive-grounded power sys-tems and phase faults in ungrounded systems.

The main c.t’s supplying the currents to the busbar protection have to fulfil only modest performance requirements (see page 11). The protection operates discriminatively for all faults inside the zone of protection and re-mains reliably stable for all faults outside the zone of protection.

Table 1:Main functions Standard Optional Special*Busbar protection X

Breaker-failure protection X

End-fault protection X

Overcurrent protection X

Overcurrent check feature X

Low voltage check feature X

Neutral current detection I0 X

Pole discrepancy protection X

Event recording X

Disturbance recording (4 x I) X

Disturbance recording (4 x I, 4 x U) X

Communication interface X

Test generator for commissioning X

Isolator supervision X

Trip redirection X

Remote HMI X* to be ordered for special applications only

REB5001MRB520256-Ben

Page 3

ABB Power Automation Numerical busbar and breaker-failure protection

Installation A REB500 busbar protection can be installed in one of three ways:

Distributed installationIn this case, the bay units (see Fig. 8 & 10) are installed in casings or cubicles in the indi-vidual switchgear bays distributed around the station and are connected to the central pro-

cessing unit by optical fibre cables. The cen-tral processing unit is normally in a centrally located cubicle or in the central relay room.

Fig. 1 Distributed layout

Centralized installation19" mounting plates with up to three bay units each, and the central processing unit are mounted according to the size of the busbar system in one or more cubicles (see Fig. 9).A centralized installation is the ideal solution

for upgrading existing stations, since very lit-tle additional wiring is required and com-pared with older kinds of busbar protection, much more functionality can be packed into the same space.

Fig. 2 Centralized installation

Combined centralized and distributed installationBasically, the only difference between a dis-tributed and a centralized scheme is the mounting location of the bay units and there-fore it is possible to mix the two philosophies.


Page 4


System design Bay unit (BU02)The hardware structure is based on a closed, monolithic casing (see Fig. 14).

Every bay unit has 16 binary inputs and 16 relay outputs. Where more binary and ana-logue inputs are needed, several bay units can be combined to form a feeder/bus coupler bay (e.g. a bus coupler bay with c.t’s on both sides of the bus-tie breaker requires two bay units).

A bay unit is the interface between the pro-tection and the primary system process com-prising the main c.t’s, isolators and circuit-breaker and performs the associated data ac-quisition, pre-processing and control func-tions. It also provides the electrical insulation between the primary system and the internal electronics of the protection.

The input transformer module contains the interposing c.t’s for measuring phase and neutral currents with terminals for 1 A and 5 A. Additional interposing c.t’s are not required, because any differences between the c.t. ratios are compensated by appropri-ately configuring the software of the respec-tive bay units.

If the option for recording voltage distur-bances as well as current disturbances has been chosen, the bay unit is equipped addi-tionally with four interposing v.t’s.

In the analogue input and processing module, the analogue current signals are converted to digital signals at a sampling rate of 48 sam-ples per period and then digitally prepro-cessed and filtered accordingly.

The binary I/O module detects and processes the positions of isolators and bus couplers, blocking signals, starting signals, external resetting signals etc. The binary input chan-nels operate according to a patented pulse modulation principle in a nominal range of 48 to 250 V DC. The application program pro-vides facility for setting the threshold voltage of the binary inputs. A time stamp is attached to all the data such as currents, binary inputs, events and diagnostic information acquired by a bay unit.

Process data are transferred at regular inter-vals from the bay units to the central process-ing unit via the process bus.

The bay unit is provided with local intelli-gence, i.e. all backup protection (e.g. breaker failure, end fault, pole discrepancy) as well as the event recorder and disturbance recorder are bay-located functions.

In the event of a failure of the central unit or an interruption of the optical fibre communi-cation, the operation of the bay unit will con-tinue and the backup protection scheme as well as the recorders (event and disturbance) will be available (stand-alone mode).

Fig. 3 Block diagram of a bay unit and a central unit

CIM

C

E

DC

DC

CPUModule

CPUModule

CPUModule

SCS/SMSInterface

RS 232Interface

Real-timeClock

Star-coupler

BinaryI/O

Star-coupler

BinaryI/O

Local HMI

Electricalinsulation

Process-bus

Filter

Binary in/outputregistersA/D

Filter

CPUE

C

Optical interface

DC

DC

DSPDP

Mem

Central Unit (CU)Bay Unit (BU02)

Local HMI


Page 5


A software logic enables the input and output channels to be assigned to the various func-tions. All the binary output channels are equipped with fast-operating relays and can be used for either signalling or tripping pur-poses (see contact data in Table 4).

The bay unit presents different mounting solutions:

• Without local HMI: ideal solution if con-venient access to all information via the central unit or by an existing substation automation system is sufficient.

• With local HMI: ideal solution for stand-alone busbar protection and kiosk mount-ing (AIS), since all information is avail-able in the bay.

For the latter option it is possible to have the HMI either built in or connected via a flexible cable. See Fig. 14.

Additional plug-and-play functionalityBay units can be added to an existing REB500 system in a simple way.

During the system start the bay unit requests its new address and the input can be made directly via its local HMI.

Central unit (CU)The hardware structure is based on standard racks and only a few different module types for the control unit.

The modules actually installed in a particular protection scheme depend on the size, com-plexity and functionality of the busbar system

A parallel bus on a frontplane mother board establishes the interconnections between the modules in a rack. The modules are inserted from the rear.

The central unit is the system manager, i.e. it configures the system, contains the busbar replica, assigns bays within the system, man-ages the sets of operating parameters, acts as process bus controller, assures synchroniza-tion of the system and controls communica-tion with the station control system.

The variables for the busbar protection func-tion are derived dynamically from the process data provided by the bay units.

The process data are transferred to the central processor via a starcoupler module. Up to 9 bay units can be connected to the first central processor and 10 to the others. Central pro-

cessors and star coupler modules are added for protection systems that include more than 9 bay units. For systems with more than 18 bay units, an additional casing or casings are required (without local HMI).

One or two binary I/O modules can be con-nected to a central processing unit. The bus-bar replica is a purely software logic without any moving parts. The busbar protection zones are determined dynamically by the bus-bar replica logic.

Busbar protection The protection algorithms are based on two well-proved measuring principles which have been applied successfully in earlier ABB low-impedance busbar protection systems:

• a stabilized differential current measure-ment

• the determination of the phase relationship between the feeder currents (phase com-parison)

The algorithms process complex current vec-tors which are obtained by Fourier analysis and only contain the fundamental frequency component. Any DC component and harmon-ics are suppressed.

The first measuring principle uses a stabilized differential current algorithm.The currents are evaluated individually for each of the phases and each section of busbar (protection zone).

Fig. 4 Tripping characteristic of the stabilized differential current algorithm.

( | | )Σ Ι

0Restraint current

( | | )Σ Ι0

IKm in

k = 1

Ksetting =kst maxTripping

area

Differentialcurrent

Restraintarea



Page 6

System design (cont´d)System design (cont´d)

ABB Power Automation

In Fig. 4, the differential current is

and the restraint current

where N is the number of feeders. The fol-lowing two conditions have to be accom-plished for the detection of an internal fault:

wherekst stabilizing factorkst max stabilization factor limit. A typical

value is kst max = 0.80IK min differential current pick-up value

The above calculations and evaluations are performed by the central unit.

The second measuring principle determines the direction of energy flow and involves comparing the phases of the currents of all the feeders connected to a busbar section.

The fundamental frequency current phasors ϕ1..n (5) are compared. In the case of an in-ternal fault, all of the feeder currents have al-most the same phase angle, while in normal operation or during an external fault at least one current is approximately 180° out of phase with the others.

The algorithm detects an internal fault when the difference between the phase angles of all the feeder currents lies within the tripping angle of the phase comparator (see Figure 5).

Fig. 5 Characteristic of the phase comparator for determining energy direction.

The task of processing the algorithms is shared between the bay units and the central processing unit. Each of the bay units contin-uously monitors the currents of its own fee-der, preprocesses them accordingly and then filters the resulting data according to a Fou-rier function. The analog data filtered in this way are then transferred at regular intervals to the central processing unit running the busbar protection algorithms.

Depending on the phase-angle of the fault, the tripping time varies at Idiff/Ikmin=≥ 5 bet-ween 20 and 30ms including the auxiliary tripping relay.

Optionally, the tripping signal can be inter-locked by a low-current or low-voltage check feature in the bay unit that enables tripping only when a current above a certain minimum is flowing, respectively the voltage is below a certain value.

Breaker-failure protection (Option)The breaker failure functions in the bay units monitor the phase currents independently of the busbar protection. They have two timers with individual settings.

Operation of the breaker-failure function is enabled either:

• internally by the busbar protection algo-rithm (and, if configured, also by overcur-rent or pole discrepancy protection fea-tures)

• externally via a binary input, e.g. by the line protection, transformer protection etc.

After the delay of the first timer has expired, a tripping command can be applied to a sec-ond tripping coil on the circuit-breaker and a

=

=N

nLnI

1DiffI

=

=N

nLnI

1RestI

maxRest

DiffIstst k

Ik >= (3)

minKDiff II > (4)

( )( )

=

LnIReLnIIm

arctann

ϕ (5)

Phase-shift

∆ϕ

74°

0° ϕ12== 36°

ϕ12== 144°

Restraint area

Case 1 2

∆ϕ max = 74°

Tripping area

Busbar

Operating characteristic

Re

Im

I1

I2

Im

ReI1

I2

180°

Case 1: External fault ∆ϕ== 144°

Case 2: Internal fault ∆ϕ = 36°

(2)

(1)


Page 7


remote tripping signal transmitted to the sta-tion at the opposite end of the line.

This first timer operates in a stand-alone mode in the bay unit.

If the fault still persists at the end of the sec-ond time delay, the breaker-failure function uses the busbar replica to trip all the other feeders supplying the same section of busbar via their bay units.

A remote tripping signal can be configured in the software to be transmitted after the first or second timer.

Phase-segregated measurements in each bay unit cope with evolving faults.

End-fault protection (Option)In order to protect the “dead zone” between a circuit-breaker and the associated c.t’s, a sig-nal derived from the breaker position and the close command is applied.

The end-fault protection is enabled a certain time after the circuit-breaker has been opened. In the event of a short circuit in the dead zone the nearest circuit-breakers are triggered.

This function is performed in a stand-alone mode in the bay unit.

Overcurrent function (Option)A definite-time overcurrent backup protec-tion scheme can be integrated in each bay unit. (The operation of the function, if param-eterized, may start the local breaker failure protection scheme).

This function is performed in a stand-alone mode in the bay unit (see page 4).

Overcurrent check feature (Option)The overcurrent check feature is only per-formed in the bay unit. It is effective for a busbar protection trip and for an intertripping signal (including end fault and breaker fail-ure) and prevents those feeders from being tripped that are conducting currents lower than the setting of the overcurrent check fea-ture.

Undervoltage check feature (special)The undervoltage criterion is registered in the bay unit. Therefore voltage transformers have to be installed at the respective feeders. The function can be configured as enabling crite-rion per zone through internal linking in the

central unit. This necessitates the existence of one set of voltage transformers per zone in one of the bay units. Tripping is only possible if the voltage falls short of the set value.

Alternatively the enabling criterion can be configured for each feeder (voltage trans-formers must be installed). (For the enabling criterion see Table 11).

Neutral current detection I0 (special)Ground fault currents in impedance-grounded systems may be too low for the stabilized dif-ferential current and phase comparison func-tions to detect. A function for detecting the neutral current is therefore also available, but only for single-phase-to-ground faults.

Pole discrepancy (Option)A pole discrepancy protection algorithm supervises that all three poles of a circuit-breakers open within a given time.

This function monitors the discrepancy bet-ween the three phase currents of the circuit-breaker.

When it picks up, the function does not send an intertripping signal to the central unit, but, if configured, it starts the local breaker failure protection (BFP logic 3).

This function is also performed in a stand-alone mode in the bay unit.

Event recordingTime stamps with a resolution of 1ms are attached to all binary events. Events are divided into the three following groups:

• system events• protection events• test eventsThe events are stored locally in the bay unit or/and in the central unit.

Disturbance recordingThis function registers the currents and the binary inputs and outputs in each bay. Volt-ages can also be optionally registered (see Table 14).

A disturbance record can be triggered by either the leading or lagging edges of binary input or output signals or events generated by the internal protection algorithms. Up to 10 general purpose binary inputs may be config-ured to enable external signals to trigger a disturbance record.



Page 8

System design (cont´d)System design (cont´d)


The number of analogue channels that can be recorded, the sampling rate and the recording period are given in Table 14.

A lower sampling rate enables a longer period to be recorded.

The total recording period can be divided into a maximum of 15 recording intervals per bay unit.

Each bay unit can record a maximum of 32 binary signals, 12 of which can be configured as trigger signals.

The function can be configured to record the pre-disturbance and post-disturbance states of the signals.

The user can also determine whether the recorded data is retained or overwritten by the next disturbance (FIFO = First In, First Out).

This function is also performed in a stand-alone mode in the bay unit (see page 4).

Note:Stored disturbance data can be transferred via the central unit to other computer systems for evaluation by programs such as WINEVE. Files are transferred in the COMTRADE format.

Communication interfaceWhere the busbar protection has to communi-cate with a station control or station monitor-ing system (SCS/SMS), a communication module is added to the central processing unit.

The module supports the interbay bus proto-cols LON and IEC 60870-5-103.

Transfer of the following are possible via a LON interbay bus:• Time synchronization• Binary events (signals, trips and diagnos-

tic)• Trip reset command• Differential currents of each protection

zone

The IEC 60870-5-103 interbay bus transfers:

• Time synchronization• Selected events listed in the public part• All binary events in the generic part• Trip reset command

• Disturbance recording data• Differential currents of each protection

zone in the generic part

Test generatorThe HMI program (REBWIN) which runs on a PC connected to either a bay unit or the cen-tral processing unit includes a test generator.

During commissioning and system mainte-nance, the test generator function enables the user to:• activate binary input and output signals• monitor system response.• test the trip circuit up to and including the

circuit-breaker (must be confirmed by the user in a dialogue)

Isolator supervisionThe system monitors any inconsistencies of the binary input circuits connected to the iso-lator auxiliary contacts and generates an alarm after a set time delay.

Trip redirectionA binary input channel can be provided to which the external signal monitoring the cir-cuit-breaker air pressure is connected. Trip-ping is not possible without active signal. When it is active, a trip generated by the respective bay unit is automatically redirected to the station at the opposite end of the line and also to the intertripping logic to trip all the circuit-breakers connected to the same section of busbar.

Human machine interface (HMI)The busbar protection is configured and maintained with the aid of human machine interfaces at three levels.

Table 2:N/O contact:“Isolator CLOSED”

N/Ccontact:“Isolator OPEN”

Isolator position

open open Last position stored+ delayed isolator alarm, + switching prohibited signal

open closed OPEN

closed open CLOSED

closed closed CLOSED+ delayed isolator alarm, + switching prohibited signal


Page 9


Local HMIAt the lowest level, control is by local control and display units installed in the central unit and optionally in the bay units. This interfacecomprises:• a four-line LCD with 16 characters each

for displaying system data and error mes-sages

• keys for controlling the display.

Amongst other things, the following can beviewed:

• measured currents, voltages and the differ-ential currents

• system status, alarms• switchgear positions• starting and tripping signals.

External HMI (REBWIN)More comprehensive and convenient control is provided by the external HMI software run-ning on a PC connected to an optical interface on the front of either the central processing unit or a bay unit. The optical interface is completely immune to electrical interfer-ence. The PC software facilitates configura-tion of the entire busbar protection, the setting of parameters and full functional checking and testing.

The HMI runs under MS WINDOWS NT and/or WINDOWS 98).

Remote HMIA second serial interface at the rear of the central unit provides facility for connecting a PC remotely via either an optical fibre or modem link. The operation and function of REBWIN is the same whether the PC is con-nected locally or remotely.

Other featuresSelf-supervision All the system functions are continuously monitored to ensure the maximum reliability and availability of the protection. In the event of a failure, incorrect response or inconsis-tency, the corresponding action is taken to establish a safe status, an alarm is given and an event is registered for subsequent diagnos-tic analysis.

Important items of hardware (e.g. auxiliary supplies, A/D converters and main and pro-gram memories) are subjected to various tests when the system is switched on and also dur-ing operation. A watchdog continuously monitors the integrity of the software func-

tions and the exchange of data via the process bus is also continuously supervised.

The processing of tripping commands is one of the most important functions from the reli-ability and dependability point of view. Accordingly, every output channel com-prises two redundant commands, which have to be enabled at regular intervals by a watch-dog. If the watchdog condition is not satis-fied, the channels are blocked.

Extension of the systemThe system functions are determined by soft-ware configured using the software configu-ration tool.

Additional system functions, e.g. breaker-failure, overcurrent or end fault protection, can be easily implemented at any time with-out extra hardware.

The system can be completely engineered in advance to correspond to the final state of the station and the software modules for new bays or features activated using the HMI when the primary plant is installed or the fea-tures are needed.

Resetting the trip commands/-signalsThe following resetting modes can be selected for each binary output (tripping or signal outputs):• Latches until manually reset• Resets automatically after a delay.

InspectionA binary input is provided that excludes a bay unit from evaluation by the protection sys-tem. It is used while performing maintenance on the primary equipment.

Redundant power supplies (Option)Two power supply modules can be fitted in a redundant arrangement, e.g. to facilitate maintenance of station batteries. This is an option for the central unit as well as for the bay unit.

Time synchronizationThe absolute time accuracy with respect to an external time reference depends on the method of synchronization used:• no external time synchronization:

accuracy approx. 1 min. per month• periodic time telegram with minute pulse

(radio or satellite clock or station control system): accuracy typically ± 10 ms


Page 10


• periodic time telegram as above with sec-ond pulse: accuracy typically ± 1 ms.

• The precise system time depends on the type of station control system and its con-figuration. The system time may also be synchronized by a 1 minute pulse applied to a binary input on the central unit.

Requirements Optical fibre cablesA distributed busbar protection layout requires optical fibre cables and connectors with the following characteristics:

• 2 optical fibre cores per bay unit• glass fibres with gradient index • diameter of core and sheath 62.5,

respectively 125 µm• maximum permissible attenuation ≤ 5 dB• FST connector (for 62.5 µm optical fibres)• rodent protected and longitudinally water-

proof if in cable ducts Observe the permissible bending radius when laying the cables.

The following attenuation figures are typical values which may be used to determine an approximate attenuation balance for each bay:

Isolator auxiliary contactAuxiliary contacts on the isolators are con-nected to binary inputs on the bay units and control the status of the busbar replica in the numerical busbar protection.

One potentially-free N/O and N/C contact are required on each isolator. The N/O contact signals that the isolator is “CLOSED” and the N/C contact that the isolator is “OPEN”. Dur-ing the closing movement, the N/O contact must close before the isolator main contact gap reaches its flashover point.

Conversely, during the opening movement, the N/O contact must not open before the iso-lator main contact gap exceeds its flashoverpoint.

If this is not the case, i.e. the contact signals ‘no longer closed’ beforehand, then the N/C contact may not signal ‘open’ before the flashover point has been exceeded.

Fig. 6 Switching sequence of the auxiliary contacts that control the busbar replica

Optical equipment Typicalattenuation

for gradient index (840nm) 3.5 dB/km

per connector 0.7 dB/km

per cable joint 0.2 dB/km

Close isolator

Flashover gap

must be closed

must be open

may be closed

Isolator

“CLOSED”normally-open

“OPEN”normally-closed

Closedend-position

Openend-position

Open isolator

Auxiliary contacts:


Page 11


Main current transformerThe algorithms and stabilization features used make the busbar protection largely insensitive to c.t. saturation phenomena. Main c.t’s types TPS (B.S. class x), TPX, TPY, 5P.. or 10P.. are permissible. TPX and TPY c.t’s may be mixed within one substation in phase-fault schemes, but not TPZ and TPX or TPY c.t’s. The relatively low c.t. performance needed for the busbar protection makes it possible for it to share protection cores with other protec-tion devices.

Current transformer requirements for sta-bility during external faultsThe minimum c.t. requirements are deter-mined by the maximum fault current.

The effective accuracy limit factor (n') must be checked to ensure the stability of the bus-bar protection during external faults.

The rated accuracy limit factor is given by the c.t. manufacturer. Taking account of the bur-den and the c.t. losses, the effective accuracy limit factor n' becomes:

where:

n = rated accuracy limit factor PB = burden at rated currentPE = c.t. lossesPB = burden at rated current

In the case of scheme with phase-by-phase measurement, n' must satisfy the following two relationships:

where:IKmax = max. primary through-fault current I1N = rated primary c.t. current

Taking the d.c. time constant of the feeder into account, the effective n' becomes:

2) n' ≥=10=for TN ≤ 120 ms, orn' ≥=50=for 120 ms <TN ≤ 300 ms.

Example: IKmax = 30000 AI1N = 1000 ATN ≤ 120 ms

Applying relationships 1) and 2):

2) n' ≥=10

Selected: n' ≥=10

Pickup for internal faultsIn the case of internal busbar faults, c.t. saturation is less likely, because each c.t. only conducts the current of its own feeder.

Should nevertheless c.t. saturation be possi-ble, it is important to check that the minimum fault current exceeds the setting for Ikmin.

Note:For systems that measure I0, the REB500 questionnaire 1MRB520258-Ken, Appendix L1, should be filled in and submitted to ABB, so that the c.t. requirements to ensure proper I0 measurement can be checked.

EB

EN

PPPPnn'

++⋅=

n ′1 IKmax⋅5 I1N⋅

-------------------≥(1)

n ′ 300005000

---------------- 6=≥(1)


Page 12


Technical data Hardware modulesTable 3: Analogue inputs (bay unit)Currents4 input channels IL1, IL2, IL3, IoRated current (IN) 1A or 5A by choice of terminals,

adjustable c.t. ratio

Thermal ratings:continuous

for 10 sfor 1 s

1 half-cycle

≥ 4 x IN

≥ 30 x IN≥ 100 x IN

≥ 250 x IN (peak)

EN60255-6 (1994),IEC 255-6 (1988), VDE 0435, part 303

EN60255-6 (1994),IEC 255-6 (1988),VDE 0435, Part 303

Burden per phase ≤ 0.1VA at IN = 1A ≤ 0.07VA at IN = 5A

Voltages (optional)4 input channels UL1, UL2, UL3, Uo

Rated voltage (UN) 100 or 200V, adjustable v.t. ratio

Thermal ratings:continuous

for 10 s

2 x UN

3 x UN

EN60255-6 (1994),IEC 255-6 (1988),VDE 0435, part 303

Burden per phase ≤ 0.3 VA at UN

Common dataRated frequency (fN) 50 Hz or 60 Hz (setting)

Table 4: Binary inputs/outputs (bay unit, central unit)Binary outputsGeneral

Operating time 3 ms (typical)

Max. operating voltage ≤ 300 V AC/DC

Max. continuous rating ≤ 8A

Max. make and carry for 0.5s ≤ 30A

Max. making power at 110 V DC ≤ 3300W

Binary output reset response, program-mable per output

- latched- automatic reset (delay 0...60 s)

Heavy-duty N/O contacts CR09 ... CR16 - bay unitHeavy-duty N/O contacts CR01 ... CR04, CR07 ... CR09 - central unitBreaking current for (L/R=40ms)

1 contact

2 contacts in series

U< 50 V DC ≤ 1.5 AU< 120 V DC ≤ 0.3 AU< 250 V DC ≤ 0.1 AU< 50 V DC ≤ 5 AU< 120 V DC ≤ 1 AU< 250 V DC ≤ 0.3 A

Signalling contacts CR01 ... CR08 - bay unitSignalling contacts CR05, CR06 - central unit


Page 13


Table 5: Auxiliary supply

Software modulesTable 6: Busbar protection

Breaking current U< 50 V DC ≤ 0.5 AU< 120 V DC ≤ 0.1 AU< 250 V DC ≤ 0.04 A

Binary inputsNumber of inputs per bay unit 16 optocouplers

8 groups with common terminal

Number of inputs for central unit 12 optocouplers per binary I/O module (max. 2)3 groups with common terminal

Voltage range (Uoc) 48 ... 250 V DCPick-up setting via HMI

Pick-up current ≥10 mA

Operating time <1 ms

Module type Bay unit Central unitInput voltage range (Uaux) ±25% 48...250 V DC 48...250 V DC

Fuse no fuse 10 A slow

Load 11 W 100 W

Common dataMax. input voltage interruption during which output voltage maintained

> 50 ms IEC 255-11 (1979) VDE 0435, Part 303

Frontplate signal green "standby" LED

Switch ON/OFF

Min. fault current pick-up setting (Ikmin)Neutral current system

500...6000 A in steps of 100 A100...6000 A

Stabilizing factor (k) 0.7...0.9 in steps of 0.05

Differential current alarmscurrent settingtime delay setting

5...50% x Ikmin in steps of 5%2...50 s in steps of 1 s

Isolator alarmtime delay 0.5...90 s

Typical tripping time 20...30 ms at Idiff/Ikmin ≥ 5 incl. tripping relays

C.t. ratio per feeder 50...10 000/1A, 50...10 000/5A, adjustable via HMI

Reset time 30...96 ms (at 1.2 < Ik/Ikmin < 20)



Page 14

Technical data (cont´d)Technical data (cont´d)


Table 8: End-fault protection

Table 7: Breaker-failure protection (optional)Measurement:

Setting range 0.1...2 x IN in steps of 0.1 x IN

Accuracy ± 5%

Timers:

Setting range for timers t1 and t2 10...5000 ms in steps of 10 ms

Accuracy ± 5%

Remote trip pulse 100...2000 ms in steps of 10 ms

Reset ratio typically 80%

Reset time 25...51 ms (at 1.2 < I/Isetting < 20)

Timer setting range 100...10,000 ms in steps of 100 ms

Current setting range 0.1...2 x IN in steps of 0.1 IN

Reset ratio 95%

Reset time 17 ms...63 ms (at 1.2 < I/Isetting < 20)

Table 9: Overcurrent functionCharacteristic definite time

Measurement:

Setting range 0.1...20 x IN in steps of 0.1 x INSetting range time delay 10 ms...20 s in steps of 10 ms

Reset ratio typically 95%

Reset time 20...60 ms (at 1.2 < I/Isetting < 20)

Table 10: Overcurrent check feature for trippingSetting range (per feeder) 0.1 IN... 4.0 IN in steps of 0.1 IN,

default 0.7 INIf the overcurrent check feature is not activated, the tripping command (“21110_Trip”) is emitted without checking that a minimum feeder current is flowing (standard).

The overcurrent check feature only enables tripping of a circuit-breaker, if the feeder current is higher than its setting. This can be individually determined for each bay.

Table 11: Undervoltage check feature for trippingSetting range (per feeder) 0.2 UN... 1.0 UN in steps of 0.1 UN,

default 0.7 UN

If the low-voltage check feature is not activated the tripping command (“21110_Trip”) is emitted unchecked (standard).

Depending on the configuration the low-voltage check feature enables tripping for each zone or tripping of a circuit-breaker by the busbar protection (or BFP intertripping etc.) and, if configured, also by the local protection functions, if the voltage falls below the low-voltage check setting. This can be individually deter-mined for each bay unit. Single-phase, three-phase and phase-to-phase configurations are possible. (In 3 ph. star configuration the phase-to-ground voltage and phase-to-phase voltages derived from the three-phase Y voltage system are evaluated).


Page 15


Table 13: Event recorder

Table 14: Disturbance recorder

Table 15: Interbay bus protocols

Table 12: Circuit-breaker pole discrepancy protectionSetting rangeTime delayDiscrepancy factor

0.2 IN ... 1.0 IN in steps of 0.1IN, default 0.7 IN100 ms ... 10000 ms in steps of 100 ms, default 1500 ms0.01* Imax ... 0.99 * Imax in steps of 0.01 * Imax, default 0.6 * Imax

For feeders with single-phase tripping and autoreclosure, the time setting for the pole discrepancy protec-tion must be greater than the reclosure time. The discrepancy factor is the maximum permissible differ-ence between the amplitudes of two phases.

Event recorder Bay unit Central unit

System eventsProtection eventsTest events

100 total 1000 total

Standard: currents (4xI)Recording period 1.5 s 2400/2880 (50/60 Hz)

3.0 s 1200/1440 (50/60 Hz)6.0 s 600/720 (50/60 Hz)

Option 1: Currents (4 x I) / Option 2: Currents and voltages (4 x I, 4 x U)Recording period 6.0 s 2400/2880 (50/60 Hz)

12.0s 1200/1440 (50/60 Hz)24.0s 600/720 (50/60 Hz)

Option 3: Currents (4 x I) / Option 4: Currents and voltages (4 x I, 4 x U)Recording period 10.0 s 2400/2880 (50/60 Hz)

20.0s 1200/1440 (50/60 Hz)40.0s 600/720 (50/60 Hz)

Number of disturbance records = total recording time / set recording period (max.15)

Independent settings for pre-fault and post-fault period (min. setting 200 ms).

LON IBB protocolLON interbay bus supports Time synchronization

Binary events (signals, trips and diagnostic)Trip reset commandsDifferential currents of each protection zone

IEC 60870-5-103 IBB protocolIEC 60870-5-103 bus supports Time synchronization

Subset of binary events as specified in IECTrip reset commandsDisturbance recording data transferGeneric mode:Differential currents of each protection zoneAll other binary events



Page 16

Technical data (cont´d)Technical data (cont´d)


Table 16: General dataTemperature range:

- operation- storage and transport

-10° C...+ 55° C- 40° C...+ 85° C

EN 60255-6 (1994), IEC 255-6 (1988)EN 60255-6 (1994), IEC 255-6 (1988)

Climate tests- Cold- Dry heat- Damp heat

-25° C / 16 h+70° C / 16 h+40° C; 95% rel. hum. / 4 days

EN 60068-2-1 (1993), IEC 68-2-1 (1990)EN 60068-2-2 (1993), IEC 68-2-2 (1974)IEC 68-2-3 (1984)

Thermal withstand of insulating materials EN 60950 (1995) Sec. 5.1

Clearance and creepage distances IEC 255-5 (1977)EN 60950 (1995), IEC 950 (1995)

Insulation resistance tests 0.5 kV / >100 MOhm IEC 255-5 (1977), VDE 0411

Dielectric tests 2 kV AC or 3 kV DC / 1 min1 kV AC or 1.4 kV DC / 1 min (across open contacts)

IEC 255-5 Cl.C (1977), EN 60950 (1995)BS 142-1966ANSI/IEEE C37.90-1989

Impulse test 1.2/50 µs/0.5 Joule5 kV AC

IEC 255-5 (1977)

Table 17: Electromagnetic compatibility (EMC)Immunity1 MHz burst disturbance tests

1.0/2.5 kV 1 MHz 400 Hz rep. freq.IEC 255-22-1, Cl. 3 (1988), ANSI/IEEE C37.90.1-1989

Immunity Industrial environment EN 50082-2 (1995)[prEN 50263/1996]

Electrostatic discharge test (ESD)

- air discharge- contact discharge

8 kV6 kV

EN 61000-4-2, Cl. 3 (1994), IEC 1000-4-2 (1995)IEC 801-2 (1991)

Fast transient test (burst) 2/4 kV EN 61000-4-4, Cl. 4 (1994), IEC 1000-4-4 (1995)IEC 801-4 (1988)

Power frequency magneticfield immunity test (50/60 Hz)- continuous field- short duration

30 A/m300 A/m

EN 61000-4-8, Cl. 4 (1993), IEC 1000-4-8 (1993)

Radio frequency interference test (RFI)

0.15 - 80 MHz, 80% ampli-tude modulated 10 V, Cl. 380 - 1000 MHz, 80% ampli-tude modulated10 V/m, Cl. 3900 MHz, 1890 MHz pulse modulated10 V/m, Cl. 3

ENV 50141,Cl. 3 (1993), IEC 1000-4-6 (1996)

ENV 50140 (1995), IEC 1000-4-3 (1995),IEC 801-3 (1984)

ENV 50204, Cl. 3 (1995)

Emission Industrial environmentTest procedure

EN 50081-2, Cl. A (1994), [prEN 50263/1996]EN 55011 (1992), CISPR 11 (1990)EN 55022 (1989), CISPR 22 (1985)


Page 17


Table 18: Mechanical tests

Table 19: Cubicle design

Table 20: Enclosure protection classes

Table 21: Optical interfaces

Vibration and shockResonance investigation 2 ... 150 Hz / 0.5 gn IEC 255-21-1 (1988), IEEE 344-1987

Permanent strength 10 ... 150 Hz / 1 gn IEC 255-21-1 (1988)

Seismic 2 ... 33 Hz 1 ... 5, 2 gn IEC 255-21-3 (1993), IEEE 344-1987EN 60255-21-3 (1995)

Shock test Cl.1; A = 15 gn; D = 11 ms;pulse/axis = 3 IEC 68-2-27 (1987), IEC 255-21-1 (1988)

Bump test Cl.1; A = 10 gn; D = 16 ms;pulse/axis = 1000 IEC 68-2-29 (1987), IEC 255-21-2 (1988)

Cubicle Standard type RESP97 (for details see 1MRB520159-Ken)

Dimensions w x d x h 800 x 800 x 2200mm (single cubicle)1600 x 800 x 2200mm (double cubicle)2400 x 800 x 2200mm (triple cubicle) *)

*) largest shipping unit

Total weight (with all units inserted)

approx. 400-600 kg per cubicle

TerminalsC.t’s 10 mm2 gauge, Phoenix URTK/S

V.t’s **) 10 mm2 gauge, Phoenix URTK/S

Power supply 10 mm2 gauge, Phoenix UK 10

Binary I/O's 4 mm2, isolating, Phoenix UDMTK 5-P/P

Internal wiring gaugesC.t’s 4 mm2 stranded

V.t’s **) 1.5 mm2 stranded

Power supply 1.5 mm2 stranded

Binary I/O's 1.5 mm2 stranded**) optional

Bay unit 19" central unit Cubicle(seeTable 19)

IP40 IP20 IP40-50

Number of cores 2 fibre cores per bay unit

Core/sheath diameter 62.5/125 µm

Max. permissible attenuation ≤ 5 dB

Max. length approx. 1200 m

Connector Type FST for 62.5 µm optical fibre cables


Page 18


Ordering Ordering and scope of supplyWhen sending your enquiry please fill in and enclose the short version of questionnaire 1MRB520258-Ken on pages 24 and 25 in this data sheet together with a single-line diagram of the station. This will enable us to submit a tender that corresponds more accurately to your needs.

At the time of ordering, fill in the full version of questionnaire 1MRB520258-Ken. These data are used by ABB to engineer the protec-tion, i.e. isolator allocation, c.t. allocation, binary inputs and outputs etc. The data given in the full version of the questionnaire is therefore binding.

The protection system is supplied fully tested and accompanied by the following documen-tation and software:

• Rack and cubicle layouts if applicable

• Three sets of documentation in either Ger-man, English or French

• System software with the plant configura-tion and parameter settings on mass stor-age media.

System tests performed in the test depart-ment:

• Installation of the system software with plant configuration and parameter settings

• Testing of busbar replica and associated protection functions

Acceptance testing can be carried out in the test department subject to prior agreement.

The delivery time applies from the receipt of the technically and commercially complete order accompanied by the full version of the questionnaire.


Page 19


Diagrams Table 22: Bay unit

* with redundant power supply

Fig. 7 Wiring diagram of bay units

Bay unit types Available inputs / outputs500 BU02_1 (4 I, 16 I/O, classic flush mounting)

500 BU02_1 (4 I, 16 I/O, stand-alone)

500 BU02_2 (4 I, 4 U*, 16 I/O, classic mounting)

500 BU02_2 (4 I, 4 U*, 16 I/O, stand-alone)

R P

Abbreviations ExplanationOCxx CRxx OLxx

Opto-coupler Tripping relay Optical link

Terminal block/ terminals

Explanation Wire gauge/ Typ

A, BC, DE

RxTx

IUP, R

Binary inputsBinary outputsOptical connectionReceive TransmitCurrentsVoltagesSupply

2.5 mm2

2.5 mm2

FST plug FST plug4 mm2 2.5 mm2

2.5 mm2

C


Page 20


Dimensioned drawings (in mm)

Fig. 8 Bay unit casing for flush mounting Enclosure Protection Class IP 40 (without local HMI)

Fig. 9 Centralized version based on a 19'' mounting plate with up to three bay units. Optionally with local HMI.


Page 21


Fig. 10 Bay unit casing for flush mountingEnclosure Protection Class IP 40(The process wiring is connected to terminals at the rear of the bay unit.)Optionally with local HMI.



Page 22

Dimensioned draw-ings (in mm) (cont´d)Dimensioned draw-ings (in mm) (cont´d)


Fig. 11 Central unit casing (19") for flush mountingEnclosure Protection Class IP 20

482.6

443

Platz für Verdrahtung Rückseite

ca. 2

3 53 0

6 U =

265

.8

2 12

**)

*)

Rear viewSpace for wiring


Page 23


Fig. 12 Front view of REB500 with various design versions incl. line protection REL316*4 (example only)

1 empty2 Central unit3 Ventilation grid4 3 bay units, stand-alone with HMI5 REL316*4 + bay unit equal to rack 46 1 bay unit, classic flush mounting

Fig. 13 Hinged frame and rear wall

Example 1: Double busbar, 11 feeders, 1 bus coupler, busbar and breaker failure protection for all bays.

1

2

3

4

5

6

Table 23: Maximum complement of modules per cubicle (centralized installation)Number of

binary I/O per bay

Max. number of bays

Number of 19” mounting

plates

Displayexample

Possibleconfiguration

16 12 4 Refer to stand-alone figures

Refer to example 1


Page 24


Fig. 14 Possible arrangements of the bay unit (BU02) with HMI.


Page 25


1. Client Client Station Client's reference Person responsible, date

2. ABB (dealt with by ABB) Tender No.: Order No.: Sales Engineer Project Manager

3. Binding Single line diagram Diagram No. Date Rev. Nr. Rev. Date Remark : (must show location and con- Please always attach

this diagram! figuration of spare bays)4. HV System System Voltage [kV] Neutral Grounding Busbar configuration

Solidly grounded Single 1-1/2 BreakerIsolated Double Ring bus

Syst. Frequency [Hz] Compensated Triple Additional Transfer busLow resistance gr. Quadruple

SwitchgearAIS GIS

5. Trip circuits Number of tripping coils (connected to REB500 tripping contacts) One trip coil Two trip coils

6. Central Unit configuration Busbar protection With Neutral Current measurementBBP IO (Special) -> for impedance grounded systems only

SCS/ SMS interface ----> Interface(Option) LON IEC 60870-5-103

Number of binary input-/ output boards (BIO) for central unit (Option)Remark: 12 binary inputs and 9 binary outputs per BIO One BIO Two BIO's

Redundant supply for the Central Unit DC Supply for central unit(Option) Udc [V]

7. Type of installation Distributed CU loose delivered Centralized CU and BU02 loose deliveredBU02 loose delivered

Distributed CU mounted in cubicle, Centralized CU and BU02 mounted in cubicles

BU02 mounted in cubicles

8. Cubicle data Syst. cubicle acc. to specification 1MRB520159-Ken (only fill in, if the BU02 and/or CU

(Specification of a cubicle type RESP97)have to be mounted in cubicles)

9. Optical fibre cable Total length for all bays (indoor type) [m] (only fill in, if an offer for optical fibre cables is explicitely desired)Total length for all bays (outdoor type) [m]

10. Documentation REB500 standard, three complete sets of documentation Number of additional sets (Optional)Language:

English German

11. Remarks

Abbreviations: CU REB500 Central Unit Definitions: (Standard) Standard function or versionBU02 REB500 Bay Units (Option) Optional function or versionSCS Station Control System (Special) For special applications onlySMS Station Monitoring Sys. 4I Four current transformersBIO Binary Input/ Output module 4I+4U Four current transformers and four voltageAIS Air isolated switchgear transformers (incl. redundant power supply)GIS Gas isolated switchgear Configuration 1-8 Depending on the protected station

equipment (line, transformer, coupler) and the toplogy of the station, the bay units could have different configurations.

HMI Human machine interface

Please tick off or write an X for a selection

Brief questionnaire


Page 26


Bay unit configuration

Example12. Type of HV Bay

Line feeder x Transformer feeder

Bus coupler/ bus section coupler

Isolator field

1 -1/2 Breaker bay

Reactor/ compensator bay13. Design of Bay unitBU02 (classic, flush mounting incl. local HMI)

4I (Standard) x

4I + 4U (Opt.)BU02 (basic version)

4I (Standard)

4I + 4U (Opt.)

Inclusive local HMI cable length= 3m

(Option)BU02 (centralized mounting)

4I (Standard)

4I + 4U (Opt.)

max. 3 BU02 per 19'' frame

Inclusive local HMI

max. 3 LMI per 19'' frame (Option)BU02 Power supply

Redundant supply for the bay units (Opt.) (**)14. Protection functions Breaker failure protection

BFP (Option) x Starting BFP

Single phase starting xThree phase starting

End fault protection

EFP (Option) Definitive time overcurrent protection

OCDT (Option) Pole discrepancy protection

PDF (Special) Under voltage release

UV (Special) (**)Over current release

OC (Special) (**)15. Disturbance Recorder DR 1.5 sec. Recording time (excl. voltage) at 2400/2880 Hz (Standard) x 6 sec. Recording time excl. Voltage

at 2400 /2880 Hz (Option) incl. Voltage (**)

10 sec. Recording time excl. Voltage

at 2400 /2880 Hz (Option) incl. Voltage (**)

16. Number of bay units Number of equipped bay units for this configuration 10 Number of pre-projected bay units (not fitted for future extension) 3(**) for this option a bay unit version 4I+4U has to be selected

ABB REB500


Page 27


Other relevantpublications

Cubicle specification RESP97 1MRB520159-KenCubicles for electronic installations 1MRB520115-BenDescription 1KHA000615-SenUser’s manual 1MRB520259-UenReference list 1MRB520009-RenOrdering questionnaire 1MRB520258-Ken


Page 28


ABB Power Automation Ltd.Haselstrasse 16/122CH-5401 Baden/SwitzerlandTel. +41 56 205 77 44Fax +41 56 205 55 77Home page: www.abb.com/ch

Printed in Switzerland (0003-1500-0)


4-1

June 2000

4. External operator program (REBWIN)

4.1. Introduction ..............................................................................4-3

4.2. Safety instructions....................................................................4-3

4.3. Installation................................................................................4-44.3.1. Minimum PC requirements.......................................................4-44.3.2. Set-up ......................................................................................4-44.3.2.1. Serial interface, off-line and simulation mode ..........................4-44.3.2.2. Mouse ......................................................................................4-54.3.2.3. Installation on a network ..........................................................4-5

4.4. Starting the operator program..................................................4-64.4.1. Window structure .....................................................................4-74.4.2. Main window ............................................................................4-8

4.5. Operation ...............................................................................4-114.5.1. File/Open ...............................................................................4-114.5.2. File/Save as ...........................................................................4-114.5.3. File/Upload from protection system........................................4-114.5.4. File/Download to protection system .......................................4-114.5.5. File/Compare with system data..............................................4-134.5.6. File/Exit ..................................................................................4-134.5.7. View/Single-line diagram........................................................4-144.5.8. View/Protection zone measurements.....................................4-164.5.9. View/Analogue input measurements......................................4-174.5.10. View/Binary inputs/output status ............................................4-184.5.11. View/Switchgear objects ........................................................4-194.5.12. View/Protection zone circuit-breakers ....................................4-194.5.13. View/Disturbance recorder.....................................................4-194.5.13.1. Recording...............................................................................4-204.5.13.2. COMTRADE...........................................................................4-204.5.13.3. Deleting..................................................................................4-204.5.13.4. Start/Stop ...............................................................................4-204.5.14. View/Event list........................................................................4-214.5.14.1. Load events ...........................................................................4-224.5.14.2. Deleting events ......................................................................4-224.5.15. View/Reset latching relays .....................................................4-234.5.16. Settings/System response .....................................................4-234.5.17. Settings/Busbar protection .....................................................4-234.5.17.1. Settings/Overcurrent release .................................................4-23


4-2

4.5.17.2. Settings/Undervoltage release ...............................................4-234.5.18. Settings/Breaker failure protection .........................................4-244.5.19. Settings/Overcurrent protection .............................................4-244.5.20. Settings/End zone protection .................................................4-244.5.21. Settings/CB pole discrepancy ................................................4-244.5.22. Settings/Event memory ..........................................................4-244.5.23. Settings/Communication ........................................................4-244.5.24. Configuration/Activate/deactivate...........................................4-244.5.25. Configuration/Isolators ...........................................................4-244.5.26. Configuration/Circuit-breaker .................................................4-254.5.27. Configuration/Current transformers........................................4-254.5.28. Configuration/Voltage transformers .......................................4-254.5.29. Configuration/Device structure...............................................4-254.5.30. Configuration/Binary module..................................................4-254.5.31. Configuration/Disturbance recorder .......................................4-254.5.32. Configuration/CB inspection...................................................4-254.5.33. Testing/Test mode .................................................................4-254.5.33.1. Purpose of the test generator ................................................4-274.5.34. Testing/Installation mode .......................................................4-284.5.35. Tools/Version .........................................................................4-294.5.36. Tools/Reports.........................................................................4-304.5.37. Tools/Change password ........................................................4-314.5.38. Tools/Settings ........................................................................4-314.5.38.1. Operator program settings .....................................................4-314.5.38.2. Database locations ................................................................4-324.5.39. Tools/Set system time............................................................4-324.5.40. Tools/MMC session manager ................................................4-334.5.41. Window ..................................................................................4-344.5.42. Help (?) ..................................................................................4-34

4.6. Error messages......................................................................4-35

4.7. Corrective action ....................................................................4-364.7.1. DAC error: 102.......................................................................4-364.7.2. Country settings, Code page..................................................4-364.7.3. Available system resources ...................................................4-36

4.8. Deinstallation .........................................................................4-36


4-3

4. External operator program (REBWIN)(See Section 5 for configuration and setting procedure)

4.1. Introduction

The REBWIN operator program enables the operator to com-municate with the REB500 protection system. The program of-fers greater convenience than the local control unit (hu-man/machine interface, HMI) with respect to viewing REB500measurements and statuses, setting the protection functions off-line and downloading the settings to REB500 and controlling theintegrated disturbance recorder.

REBWIN runs on a standard PC (see Section 4.3.1. “MinimumPC requirements”) under Windows 98 or NT.

The data are transferred between the PC and REB500 via anoptical serial interface located on the front of the REB500 units.

4.2. Safety instructions

Danger: The REBWIN operator program permits circuit-breakers and isolators to be operated. Every program operationand the possible consequences must be considered carefullybeforehand. If switching operations have to be carried out, thesame precautions must be taken as when performing themmanually.

Caution: Version 5.0x of the REB500 of the protection softwarerequires Version 5.0x of REBWIN. Earlier REBWIN versions areincompatible.

Caution: A password has to be entered to operate REBWIN.Passwords may only be assigned to competent authorised op-erators. Change the standard passwords in the software assoon as the program is installed.


4-4

4.3. Installation

Making a backup copy of the original REBWIN discs and usingthe backup copy for the installation is recommended. Providingthe corresponding operating system option is activated, youmust have administrator access rights to install the program onthe PC.

4.3.1. Minimum PC requirements

The PC control program runs on an IBM PC or compatible underMS Windows 98 or NT 4.0. The minimum performance require-ments are as follows:

PC with a 100 MHz Pentium processor or higher

mouse plus PS/2 interface (bus board) if the PC has only oneserial interface

Windows 98 or NT 4.0

16 MByte RAM (32 MByte recommended)

1 floppy (3½", 1.44 MByte) or CD drive

1 serial interface (RS-232C) (COM1 or COM2)

SVGA monitor (800 x 600)

1 parallel interface (LPT1) for a printer (recommended).

4.3.2. Set-up

Deactivate any anti-virus program you may have running on thePC before installing REBWIN. The anti-virus program can be re-activated once the installation of REBWIN is complete.

Insert the disc “1/5 (Setup)” or the program CD in the corre-sponding drive and run the program “SETUP.EXE”. Enter an in-stallation directory of your choice should you not wish to use thedefault directory. You are requested to insert the second disconce all the files have been copied from the first and so on.

The installation routine automatically creates a REBWIN pro-gram group and the program icon “REBWIN x.xx ss”, x.xx signi-fying the program version and ss the language.

4.3.2.1. Serial interface, off-line and simulation mode

By default, the installation routine will select the first free inter-face (COM port). The communication settings can be changedsubsequently by selecting “Tools/Settings” (see Section 4.5.38.).The same menu item also provides a choice of operating modeby selecting either the radio button “On-line” (excludes the func-


4-5

tions requiring a REB500 to be connected) or “Simulated” (noREB500 connected, but with all the functions available for dem-onstration purposes and random generation of data).

Note: REBWIN automatically starts off-line, if an invalid COMport is entered or another application is using the port.

4.3.2.2. Mouse

A mouse is necessary to work with the REBWIN operator pro-gram efficiently. It is possible to control it solely via the keyboard,but this can be a little cumbersome. The right mouse button isalso used for some operations and therefore it should not beconfigured to perform other functions (e.g. double click).

4.3.2.3. Installation on a network

Before attempting to install REBWIN on a network, ascertainthat you are authorised to write in the corresponding Widows di-rectory, otherwise the installation will fail.


4-6

4.4. Starting the operator program

Note: The program screens in this Section are based on a typi-cal application. Depending on the power system configurationand the options configured while engineering your system, cer-tain menus may be missing or the display appear different.

The first screen to appear after starting the operator program isthe “System log-on” dialogue:

Figure 4.1 System log-on dialogue

The program can be run in a read only mode by appropriatelyactivating the “Read only” check box, i.e. the data can be viewedbut not changed. Users that want to run the program in aread/write mode must enter a password.

Note: To enable a start to be made, the password is set to “Sys-tem” when the program is supplied (case sensitive!).

The operator program obtains the specific device data from adatabase in a file which is stored both on the PC and the protec-tion system. Database files on the PC have the extension “.mdb”.

Click on the “OK” button to continue the start-up routine or onthe “Cancel” button to discontinue and close the program.

The main window with the main menu bar appears after clickingon “OK”.


4-7

Some of the dialogues used by the program are standard Win-dows dialogues. Should these not be in the same language asREBWIN, then a different language is set for the Windows oper-ating system.

Note: The database that was open during the last sessionopens automatically. If a database was never opened before,select “Open” in the “File” menu and then the desired file. Anerror message is displayed if an attempt is made to open anincompatible file. An existing file in the protection system canalso be opened using the “Upload” function in the “File” menu.

Figure 4.2 Main REBWIN window

4.4.1. Window structure

The structure and handling of the windows in the operator pro-gram is similar to other Windows applications.

Figure 4.3 Dialogue buttons


4-8

The following buttons appear in many dialogues:

OK

The new settings are saved in the database on the PC and thedialogue closes.

Apply

The new settings are saved in the database on the PC and thedialogue stays open.

Restore

The changes that have been made are ignored and the old set-tings restored.

Cancel

The new settings are not saved and the dialogue closes.

Scroll (arrow) buttons

In windows permitting the selection of several bays (or isolators,circuit-breakers etc.), there are four scroll buttons at the bottomfor scrolling through the bays.

Close

The window or dialogue is closed and a warning is displayed, ifchanges have been made which have not been saved.

In many dialogues with settings there is an overview tab for se-lecting one of a list of bays and a details tab showing the re-spective settings. The details can be viewed by either clicking onthe tab or double-clicking on the bay in the overview list.

4.4.2. Main window

The title bar is at the top of the main program window and statesthe name of the program “REBWIN (REB500)” and the projectinformation entered by the ABB engineering department. Themenu bar is located immediately below the title bar.

Figure 4.4 Main menu of the REBWIN operator program


4-9

File

The menu item “File” permits databases to be opened andsaved and a database to be uploaded from the protection ordownloaded to it.

View

The menu item “View” contains menu items for viewing theplant diagram, the measurements of each protection zone, in-puts and outputs, switchgear statuses, the event list and anytripping that has taken place.

Settings

The menu item “Settings” provides facility for setting the sys-tem parameters, the operating values for the various protec-tion functions and the communication parameters.

Configuration

The menu item “Configuration” concerns the definition of thevarious circuit-breakers, isolators and c.t’s, the activa-tion/deactivation (masking/unmasking) of items of plant, theconfiguration of system modules, tripping logics-breakers andthe disturbance recorder and the planning of maintenance.

Testing

The menu item “Test” is for enabling/disabling either the testor installation mode.

Tools

Functions for entering data file versions, producing reports,changing passwords, selecting operator program options andsetting the system time are available under the menu item“Tools”.

Status information is displayed on the bar at the bottom of themain window (Ready, On-line/Off-line, Edit/Read only, Test mode,Installation mode). These have the following significance:

Figure 4.5 Status bar

Ready

Signals that the program is standing by.


4-10

On-line/Off-line

If the program can successfully establish contact with theprotection system, it is in the on-line mode. If no connectioncan be established or is not desired the program is in the off-line mode.

Edit/Read only

“Edit” permits settings to be saved in a file or downloaded tothe protection system. In the “Read only” mode it is only pos-sible to read data.

Test mode

“Test mode” is displayed on the status line whenever the testgenerator is activated.

Installation mode

“Installation mode” is displayed on the status line wheneverthe installation mode is activated.

Simulation

“Simulation” is displayed on the status line whenever thesimulation mode is activated. This permits all the functions tobe executed without being connected to a protection device. Ifdata should be uploaded from the protection system, e.g. anevent list or measurements, the simulation mode generatesrandom values. These may correspond to fault situations.


4-11

4.5. Operation

4.5.1. File/Open

After starting the program, select “Open” from the “File” menu. Adialogue opens which enables you to select the desired file. Thedialogue provides facility for navigating through the variousdrives and directories. After making the corresponding choice,click on “OK” to load the data into the program or on “Cancel” toclose the dialogue without making any changes.

4.5.2. File/Save as

The current data in the PC database can be saved in a file byopening the “File” menu and clicking on “Save as”. As was thecase with “Open”, the dialogue that appears gives full access tothe PC file system.

4.5.3. File/Upload from protection system

This menu item enables data stored in the protection system tobe uploaded to a file in the PC.

Figure 4.6 Upload from protection system

4.5.4. File/Download to protection system

Open the “File” menu and select “Download to protection sys-tem” to download the current data from the PC database to theprotection system.

The versions are compared before downloading proceeds andthe result is displayed. An index and a comment may also beentered beforehand by selecting Tools/Version (see Section4.5.35.). The new data is only saved if it is different. Data willonly be saved if they are different or the version index is different.

Note: Data will only be correctly downloaded providing the pro-tection system has been correctly started.


4-12

After the downloading procedure is complete, the protectionsystem is restarted and the valid version can then be verified onthe HMI.

Figure 4.7 Download to protection system and comparison ofversions

Figure 4.8 Download to protection system and comparison ofversions

The progress of the downloading procedure is shown on thescreen. The correct time format must be set via the control panelon the PC for the procedure to be presented correctly. While thedata are actually being transferred to the protection system, theradio button “Download all data to the system” is red. The pro-cedure can still be aborted at this stage by clicking on the “Can-cel” button.


4-13

Figure 4.9 Download to protection system

Various check sums are calculated to establish the integrity ofthe data in the database and these are examined after thetransfer of data has been completed.Only after all the data have been successfully transferred arethey saved in the non-volatile memory.

4.5.5. File/Compare with system data

Provision is made for checking whether the configuration andsetting data in the protection system and the PC are the same.The comparison procedure does not identify data that differ.

4.5.6. File/Exit

To terminate the program, open the “File” menu and select“Exit”. A warning is displayed if there are changes that have notbeen saved. You then have the choice of saving or discardingthem.


4-14

4.5.7. View/Single-line diagram

Opening the “View” menu and selecting “Single-line diagram”displays diagram of the plant corresponding to the layout andwiring diagrams created for the project by the ABB engineeringdepartment.

The screen below shows a typical single-line diagram:

Figure 4.10 Single-line diagram

The name of every item of plant can be changed by pointing atits label and clicking the right mouse button. This opens a menuwith the operation “Change label”. Clicking the right mousebutton again on this command opens a dialogue called “Newlabel”. After entering the new name, click on “OK” to confirm it.

The primary system shown above is only an example.

Providing the items of plant have been configured, updatingonce or cyclically shows their actual status and the feeder cur-rents. Using the right mouse button, it is also possible to displaythe differential currents of the selected busbar zone. A busbarzone is selected by clicking the right mouse button on its label,e.g. BZ1.


4-15

Figure 4.11 Updated single-line diagram(Click the right mouse button in the empty field to update thesymbol bar.)


4-16

4.5.8. View/Protection zone measurements

This dialogue displays the actual values of measured variablesfor each protection zone. The protection zones are determinedby the positions of the isolators and the bus-tie breakers (busbarimage).

Overview

Figure 4.12 Overview dialogue for protection zone measure-ments

The currently active protection zones are listed in order showingthe associated sections of busbar and the differential current perphase or in the neutral. The overview is not updated automati-cally, it is necessary to click on the “Refresh” button.

A protection zone to which no measurement has been assignedat all is shown as being invalid.


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4.5.9. View/Analogue input measurements

The bay units and their labels and slots are listed in the overviewdialogue.

Figure 4.13 Overview dialogue for protection zone measure-ments

To display the values of measured variables, first select a mod-ule (becomes highlighted) and click on the “Open measurementswindow” button or alternatively double click on the module. Up toeight measurement windows can be open at the same time.

The windows can be arranged under each other by clicking onthe “Arrange windows” button.

The display is not updated automatically, it is necessary to clickon the “Update measurement” button. This updates all themeasurement windows simultaneously.

A warning appears in the measurement window if measure-ments cannot be correctly performed. Closing the overview win-dow closes all the measurement windows as well.


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4.5.10. View/Binary inputs/output status

Figure 4.14 Binary input/output statusThe binary inputs and outputs are listed in the overview dialoguetogether with their bay labels and slot numbers.

To view a signal status, select the corresponding module andclick on the “Open status window” button or alternatively doubleclick on the module. Up to eight status windows can be open atthe same time. They can be arranged under each other byclicking on the “Arrange windows” button.

The display is not updated automatically, it is necessary to clickon the “Update status” button. This updates all the status win-dows simultaneously.

A status window shows either the inputs or the outputs. A “1” ina field indicates that the respective input or output is set and a“0” that it is reset. The statuses of all valid values are green(grey on a monochrome screen).A status of an input or output that has been impressed via themenu “Testing/Test mode” (see Section 4.5.33.) is yellow (whiteon a monochrome screen).The statuses of inputs which the monitor has tagged as beinginvalid are red. This can also occur briefly when the window isopened.

Closing the overview window closes all the status windows aswell.


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Note: Further details of the signals assigned to the various bi-nary inputs and outputs can be viewed by opening the “Configu-ration” menu and selecting “Binary modules” (see Section4.5.30. “Configuration/Binary module”).

4.5.11. View/Switchgear objects

This dialogue shows the positions of circuit-breakers and isola-tors.

Figure 4.15 Switchgear objects

4.5.12. View/Protection zone circuit-breakers

All the circuit-breakers belonging to the respective protectionzone are displayed.

4.5.13. View/Disturbance recorder

The current status of every bay unit can be viewed.

The sampling frequency can be set to either 600/720 Hz,1200/1440 Hz or 2400/2880 Hz.

Recording can also be started, deleted or transferred manuallyto the PC in the COMTRADE format (*.cfg). Records have to beexplicitly deleted.


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4.5.13.1. Recording

A trigger signal is sent to all the disturbance recorders that havebeen configured.

4.5.13.2. COMTRADE

It is only possible to access the oldest record for deleting orsaving operations.

COMTRADE files are saved using the usual Microsoft Windowsfunction “Save as” which proposes the default file format:

dddsssnn.CFG

where ddd Day of the year (1...365)sss Disturbance recorder station numbernn Consecutive disturbance recorder number.

A file each with the extension *.DAT and one with the extension*.HDR are also created.

4.5.13.3. Deleting

Only the oldest record is deleted.

4.5.13.4. Start/Stop

This concerns the disturbance recorder function. The trigger isinactive in the “Not ready” mode and therefore also the distur-bance recorder.

Providing the disturbance recorder function is configured onseveral bay units, a number can be selected and their data up-loaded in a single operation. This function is also available in theautomatic mode which scans the units periodically. For this pur-pose the “Delete disturbance recorder records after successfulupload” box must be checked.


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Figure 4.16 Uploading disturbance recorder records

4.5.14. View/Event list

Protection system events are shown in chronological order. Bycorrespondingly setting the event filter, just protection events,system events or test events can be viewed separately.

Figure 4.17 Event listThe central unit event list has a maximum length of 1000 andthe bay units 100 records.

In the event of a supply failure, the events stored in the REB500central unit remain intact for at least 24 hours.


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4.5.14.1. Load events

The protection system has an event memory for every unit (cen-tral unit and bay units).

To upload the latest events to the PC, open the “View” menuand select “Event list”. This opens the “Event list” dialogue (theoperator program must be in the on-line mode). Click on the“Refresh” button to upload the events. The protection systemstores the events until they are explicitly deleted.

The list viewed on the PC is refreshed either on command or cy-clically. To specify the refreshing interval, select “Tools” and then“Settings” (see Section 4.5.38.).

There is no indication should the event memory overflow be-fore the events have been uploaded. The events are updated asdetermined by the system response setting (see Section 4.5.22“Settings/Event memory”).

The following information is shown for every event:

• Type of eventP = Protection function eventS = System eventT = Test generator event

• Date event occurred

• Time event occurred

• Source of event with application, node and device ID

• Text as entered via “Configuration/Binary module”

• Value, e.g. ON or OFF.

The width of the columns can be adjusted by dragging the bor-der with the mouse in the table header.

Providing a printer is connected to the PC, you can print theevent list by clicking on the “Print” button.

The event list can be saved to a text file on the PC with the aidof ASCII export.

4.5.14.2. Deleting events

An event is marked (becomes highlighted) by clicking on it withthe mouse and several events by holding the mouse buttonpressed and moving the pointer over them.Clicking in the blank field at the top left of the window (next to‘Type’) marks all the events in the list.


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Deleting the PC list

Mark events you wish to delete and click on the “Delete PC list”button. Deleting can take several seconds and single events,groups of events or all events can be deleted.

Deleting the system list

All the events stored in the protection system are deleted.

Deleting events that have been viewed

All the protection events viewed since opening the window aredeleted.

System events when starting

A number of system signals that are generated when starting thesystem are recorded as events. Up to the instant that systemclocks are automatically synchronised, events may have an in-correct date and time.

4.5.15. View/Reset latching relays

Figure 4.18 Resetting latched tripping and signalling relaysAll latched signals are reset and the corresponding display onthe local control unit deleted.

4.5.16. Settings/System response

See Section 5.4.2. “Settings/System response”.

4.5.17. Settings/Busbar protection

See Section 5.4.3. “Settings/Busbar protection” (settings andcalculations).

4.5.17.1. Settings/Overcurrent release

See Section 11.6.3. “Overcurrent check”.

4.5.17.2. Settings/Undervoltage release

See Section 11.6. “Enabling the tripping command”.


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4.5.18. Settings/Breaker failure protection

The setting dialogue for the breaker failure protection is onlyavailable providing the function is part of the scope of supply.

See Section 11.1. “Breaker failure protection”.

4.5.19. Settings/Overcurrent protection

The setting dialogue for the time-overcurrent protection is onlyavailable providing the function is part of the scope of supply.

See Section 11.3. “Time-overcurrent protection”.

4.5.20. Settings/End zone protection

The setting dialogue for the end zone protection is only availableproviding the function is part of the scope of supply.

See Section 11.2. “End zone protection”.

4.5.21. Settings/CB pole discrepancy

The setting dialogue for the CB pole discrepancy function is onlyavailable providing it is part of the scope of supply.

See Section 11.4. “Circuit-breaker pole discrepancy function”.

4.5.22. Settings/Event memory

See Section 5.4.8. “Event memory”.

4.5.23. Settings/Communication

Providing the corresponding hardware has been fitted, the bus-bar protection can communicate with a station automation sys-tem (SCS) or station monitoring system (SMS) via the interbaybus connector.

See Section 11.8. “Interbay bus (IBB) connector”.

4.5.24. Configuration/Activate/deactivate

Entire bay units or individual items of plant can be activated or de-activated, i.e. included in or excluded from the protection system.

See Section 8.1.9.4. “Activating and deactivating feeders”.

4.5.25. Configuration/Isolators

This menu item permits the isolator labels to be changed.

See Section 5.3.2. “Configuration/Isolators”.


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4.5.26. Configuration/Circuit-breaker

This menu item permits the circuit-breaker labels to be changed.

See Section 5.3.3. “Configuration/Circuit-breakers”.

4.5.27. Configuration/Current transformers

This menu item permits the c.t. labels and ratios to be changed.

See Section 5.3.4. “Configuration/Current transformers”.

4.5.28. Configuration/Voltage transformers

This menu item only appears if the protection system includesv.t’s.

See options and Section 11.6.1.1. “Configuration/Voltage trans-formers”.

4.5.29. Configuration/Device structure

See Section 5.3.6. “Configuration/Device structure”.

4.5.30. Configuration/Binary module

See Section 5.3.7. “Configuration/Binary module”.

4.5.31. Configuration/Disturbance recorder

See Section 5.3.8. “Configuration/Disturbance recorder”.

4.5.32. Configuration/CB inspection

See Section 5.3.9. “Configuration/CB inspection”.

4.5.33. Testing/Test mode

Caution: Switching to the test mode while the protection is inoperation is not recommended because of the danger of falsetripping if the consequences of changing statuses is not fullyconsidered.

The test generator is activated by opening the “Testing” menu,selecting “Test mode” and entering a valid password. A tick ap-pears next to the menu item, “Test mode” appears on the statusline at the bottom of the screen and the “Test mode” dialogueappears.


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Note: To enable a start to be made, the password is set to“Test” when the program is supplied.

The test generator is used in conjunction with the “Status of bi-nary inputs/outputs” dialogue (has to be opened by the operator)(see Section 4.5.10. “View/Binary inputs/output status”).

When the test generator is active, the statuses of the trippingcommands cannot change.

Figure 4.19 Test mode

Unblock all relays

Clicking on the “Unblock all relays” button restores the relays tonormal operation and their statuses can change again.

Caution: An output relay can now be set or reset either di-rectly or indirectly (e.g. via an input or by a protection func-tion).

The greatest care must be taken when using the test mode,especially when the protection system is in operation.

Block all relays

Clicking on the “Block all relays” button prevents the statuses ofall relays for which outputs have been configured from beingchanged.


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ception of “41810_In service”, “41835_Test generator active”and “41410_Output relays blocked”.

Reset all overridden relays

Clicking on the “Reset all overridden relays” button returns all in-puts and outputs which have had statuses impressed on themfor test purposes to their original states.

4.5.33.1. Purpose of the test generator

Figure 4.20 Test modeIn order to set or reset binary inputs and outputs using the testgenerator, it is necessary to open the “Status of binary in-puts/outputs” dialogue. Providing the test mode is active, thestatus of an input or output can be changed by simply double-clicking on it. The display must then be refreshed by clicking onthe “Update status” button in the “Status of binary in-puts/outputs” dialogue.

The test generator is deactivated by clicking on the menu item“Test mode” a second time. All the relays are then restored totheir original statuses, any latching is reset and blocking by thetest generator is cancelled.

Regardless of whether they are logical ‘0’ or logical ‘1’, inputsand outputs are normally green, those with impressed statusesyellow and invalid ones red. Impressed statuses are green afterthe display is refreshed.


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Exiting the test generator

• Overridden signals are restored to their previous statuses.

• Latched outputs are reset.

• All the outputs that were blocked during testing are enabledagain.

4.5.34. Testing/Installation mode

This mode is activated by opening the “Testing” menu, selecting“Installation mode” and entering a valid password.

A tick appears next to the menu item, “Installation mode” is dis-played on the status line at the bottom of the screen and the “In-stallation mode” dialogue opens.

Click on “Installation mode” in the “Testing” menu to reset the in-stallation mode.

Note: To enable a start to be made, the password is set to “In-stall” when the program is supplied.

Figure 4.21 Restart the protection system


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Figure 4.22 Delete database in the protection system

Delete data base in the protection system

All the data in the protection system are deleted.

Restart the protection system

Clicking on the “Restart the protection system” button reinitial-ises the protection.

Debug mode

In the debug mode, the protection system generates additionalinternal program events.

Read traceability information

The hardware data (type, serial number, revision index, date ofmanufacture etc.) and software data (version) are uploaded fromthe protection equipment and stored in the database to enableprevious history to be retraced.

4.5.35. Tools/Version

This menu item is for administering the data of the specific pro-tection system such as settings, event texts, configuration of thebinary inputs and outputs etc., in the database. Parts of the da-tabase can be edited using the REWIN operator program on thePC and then downloaded to the protection. The database has aversion number and index that are displayed in the main menuof the local control unit.

Version: X.YY, date of the last change, description


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The version is purely numerical, i.e. X 1...9 and Y 1...9. It isassigned by ABB Power Automation while processing the con-tract and determined at the time the system is accepted by theuser. The user cannot change it subsequently.

Index: XX, date of the last change, description

The index only comprises letters, i.e. X A...Z. The user has thepossibility of changing the index and its description if he changesthe REB500 settings in order to document and distinguish differ-ent sets of settings. When a new index is assigned, the currentdate on the PC is recorded as the date of the last change.

Figure 4.23 Version

4.5.36. Tools/Reports

Figure 4.24 Reports


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Open the “Tools” menu and select “Reports” to open the “Reports”selection dialogue containing a list of different kinds of reports.

Either a desired report can be printed on its own or all the re-ports can be printed by activating the “Print all reports” check box.The difference between the options in the “Printing quality” fieldis that the data are presented in tabular form if the “Normal” ra-dio button is active.

Unless a printer is actually installed on the PC, the “Reports”menu item is grey and inactive. A printer does not, however,have to be connected.

4.5.37. Tools/Change password

This menu item provides facility for changing the passwordsgiving access to various protected functions (changing settingsand activating the test mode or installation mode). Passwordsapply to the operator program on the PC and not for the protec-tion system.

4.5.38. Tools/Settings

4.5.38.1. Operator program settings

Some of the operator program functions can be customised:

Figure 4.25 Operator program settings

Communication mode

This group includes radio buttons for selecting whether the op-erator program should operate on-line with the protection or in


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the simulation mode without the protection and also the interface(COM port) via which on-line communication should take place.

Write DB download/upload log file

If these are set to yes, a log file is saved every time the data-base is downloaded to, respectively uploaded from the protec-tion system.

Parameters for reading and exporting event data

Settings are provided for the period for cyclically reading eventsand the separator for an ASCII file when exporting events.

4.5.38.2. Database locationsThe operator program creates a number of configuration data-bases. The following dialogue provides facility for defining the di-rectories where the databases are located and changing thedatabase names. Default directories are created during the in-stallation of REBWIN and it is recommended that these not bechanged.

Figure 4.26 Tools/Settings/Database locations

4.5.39. Tools/Set system time

The system clock in the protection system is equipped with astandby battery and runs independently with an accuracy of150 ppm (13 s per day), unless the time is not synchronised pe-riodically by an external reference. The date and time are set byopening the “Tools” menu and selecting “Set system time”. Thedate and time displayed are those effective on the PC.


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The settings in the fields can be incremented or decremented byclicking on the appropriate arrow to the right of the value. Aftermaking the necessary changes, click on the “Set time” button toautomatically download the new date and time to the protectionsystem.

Figure 4.27 Setting the system timeThis menu item is not available if a communication interface foran station automation system (SCS) is configured.

4.5.40. Tools/MMC session manager

Figure 4.28 MMC session managerAs a rule, this function runs entirely automatically and requiresno intervention by the operator. Only if after something untowardhappens and an error message is displayed is it necessary tomanually close sessions (e.g. if the PC is switched off withoutcorrectly shutting down the program).

Every transaction involving communication between the operatorprogram and the protection system (e.g. reading the event list or


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setting inputs and outputs using the test generator) is managedas a (DAC) session. Open the “Tools” menu and select “MMCsession manager” to open a dialogue with a list of open ses-sions.

Mark the sessions which have been aborted and have to beclosed and then click on the “Close session” button. Take carewhen doing so that no other PC is connected to any other part ofthe protection system as its communication may also be termi-nated.

The session “TGR_Read EMI” monitors the main communica-tion between the operator PC and the protection system andmust remain open. The operator program must be shut downand restarted should the “TGR_Read EMI” session be closed bymistake.

4.5.41. Window

When several windows are in use, this menu provides facility forarranging them to overlap, under each other or next to eachother.

4.5.42. Help (?)

AboutThis provides information on the program version and the PCsystem (available memory etc.).


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4.6. Error messages

No. Text Cause / Description Action

102 Write sessionExist

1. The same function(e.g. upload events)was called from asecond PC.

2. The connectionPC/protection systemwas interrupted with-out closing the MMCprogram.

For 1.Wait till the operation bythe other PC is finished.

For 2.Close all sessions via the“Tools” menu and “MMCsession manager” andrestart REBWIN (no otherPC may be on-line with theprotection system).

103 Invalid session As 102 As 102

1004 TDB_Protocol_Error

Communication or in-ternal SW error

Check all connections tothe protection and repeatthe operation. Notify ABB ifthe error/failure persists.

1006 TDB_Buffer_Error Internal SW error Restart the operator pro-gram or PC.Notify ABB if the error/failure persists.

2002 TGR_Is_Busy Function could not beexecuted.

Repeat operation.

2003 TGR_No_Session Statuses can only beimpressed in the testmode.

Switch to test mode.

2004 TGR_Address_Not_Handled

The configuration datain the open data basedo not agree with theeffective system con-figuration.

Check the REBWIN database (correct plant database?).

2005 TGR_Configuration_Error

Invalid data down-loaded to the protectionsystem.

Download the data to theprotection system again.

2006 TGR_Not_Responding

No communicationbetween central andbay units

Check the optical fibrecable connections betweencentral and bay units.

xxxx Internal SW error Notify ABB.

Table 4.1 Error messages displayed by the REBWIN op-erator program


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4.7. Corrective action(See Section 9 “Corrective action”)

4.7.1. DAC error: 102

It is not possible for more than one PC to access the event list ata time. If an operator using a second PC attempts do so, themessage DAC error 102 is displayed. With this exception, thelimited connection of several PC’s is possible.

4.7.2. Country settings, Code page

The ABB engineering department configures all REB500 sys-tems for Code page 850 (multilingual, Latin).The currently active code page can be viewed by entering theDOS command “chcp”. Please consult the instructions for youroperating system for how to change the code page.For example, the entry on the country line in the “CONFIG.SYS”file could be:

country = 041,850,\dos\country.sys

4.7.3. Available system resources

Should your PC’s system resources fall below 20 % after startingREBWIN (select “About” in the “Help” menu and click on “Sys-tem info”), REBWIN may not function correctly. In this case,close all other Windows applications.

4.8. Deinstallation

Run the deinstallation program Unwise.exe in the REBWIN pro-gram directory (default C:\Program Files\REB500\REBWIN5.00US).


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June 2000

5. CONFIGURATION AND SETTINGS

5.1. Introduction ..............................................................................5-3

5.2. “View” menu .............................................................................5-3

5.3. “Configuration” menu ...............................................................5-45.3.1. Configuration/ Activate/deactivate............................................5-45.3.2. Configuration/Isolators .............................................................5-45.3.3. Configuration/Circuit-breaker ...................................................5-65.3.4. Configuration/Current transformers..........................................5-85.3.5. Configuration/Voltage transformers..........................................5-85.3.6. Configuration/Device structure .................................................5-95.3.6.1. Overview ..................................................................................5-95.3.6.2. Details ......................................................................................5-95.3.7. Configuration/Binary module ..................................................5-115.3.7.1. Overview ................................................................................5-115.3.7.2. Binary inputs ..........................................................................5-125.3.7.3. Binary inputs on the bay units ................................................5-175.3.7.4. Binary inputs on the central unit .............................................5-235.3.7.5. Binary outputs ........................................................................5-255.3.7.6. Binary outputs on the bay units ..............................................5-295.3.7.7. Binary outputs on the central unit...........................................5-325.3.8. Configuration/Disturbance recorder .......................................5-355.3.8.1. Analogue inputs .....................................................................5-355.3.8.2. Recording...............................................................................5-365.3.8.3. Binary channels......................................................................5-365.3.8.4. Signals ...................................................................................5-375.3.9. Configuration/CB inspection...................................................5-40

5.4. Settings and calculations .......................................................5-415.4.1. Rated frequency (not adjustable) ...........................................5-415.4.2. Settings/System response......................................................5-415.4.2.1. System response to a differential current alarm.....................5-415.4.2.2. System response to an isolator alarm....................................5-415.4.2.3. Isolator alarm delay................................................................5-425.4.2.4. Remote trip impulse width ......................................................5-435.4.3. Busbar protection (settings and calculations).........................5-445.4.3.1. Restrained amplitude comparison — IKmin and k ...................5-465.4.3.2. Application example ...............................................................5-475.4.3.3. Busbar with just two feeders ..................................................5-495.4.3.4. Busbar with several feeders ...................................................5-49

ABB Power Automation Ltd 1MRB520259-Uen / Rev. A REB500

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5.4.3.5. Busbar fault with through current ...........................................5-515.4.3.6. Differential current alarm setting ............................................5-535.4.3.7. Differential current alarm delay setting...................................5-545.4.3.8. Neutral current supervision (operating characteristic L0)........5-545.4.3.9. Phase comparison .................................................................5-545.4.3.10. Overcurrent check for enabling tripping .................................5-545.4.3.11. Undervoltage check for enabling tripping ...............................5-555.4.4. Breaker backup protection .....................................................5-555.4.5. End fault protection ................................................................5-555.4.6. Time-overcurrent protection ...................................................5-555.4.7. Circuit-breaker pole discrepancy function ..............................5-555.4.8. Event memory ........................................................................5-55


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5. CONFIGURATION AND SETTINGS

5.1. Introduction

The REB500 busbar protection system is configured on the ba-sis of the customer’s specification resulting from his response toa questionnaire.

The following information is intended to enable the user to un-derstand the choice of REB500 settings and to follow their cal-culation.

The basic configuration of the REB500 system is performed byABB. There are some additional settings that the user has tomake.

In this Section, the various menus and submenus are explainedthat require settings or the input of text by the user.

5.2. “View” menu

Single-line diagram:

Figure 5.1 Single-line diagram in the “View” menu

Right clicking an item opens a dialogue for changing its label.


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5.3. “Configuration” menu

Figure 5.2 Menu items in the configuration menu

5.3.1. Configuration/ Activate/deactivate

This menu item is used to activate or deactivate items of plant inthe single-line diagram so that it agrees with the actual state ofthe primary system (see Section 8.1.9.4. “Activating and deacti-vating feeders”).

5.3.2. Configuration/Isolators

Changing isolator labels:

Overview

Figure 5.3 Overview tab in the “Configuration/Isolator” dia-logue


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The “Overview” tab opens a dialogue with a list of all the isola-tors in the single-line diagram with their labels and bay unit la-bels.

An isolator in a particular bay can be viewed by activating thecheck box “Feeder filter” and selecting a bay from the list.

Details

Figure 5.4 Details tab in the “Configuration/Isolator” dialogue

The label in the “Markings” field can be edited.

The arrows to the left and right of “Select isolator” at the bottomof the dialogue enable you to scroll through the entire list.


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5.3.3. Configuration/Circuit-breaker

Changing circuit-breaker labels:

Overview

Figure 5.5 Overview tab in the “Configuration/Circuit-breakers”dialogue

All the feeder circuit-breakers and bus-tie breakers shown in thesingle-line diagram are listed in this dialogue together with theirlabels, bay labels, type of circuit-breaker (feeder or bus-tie) andthe reclaim time.

DetailsThe label in the “Label” field can be edited and the reclaim timefor each circuit-breaker is entered in the corresponding field.

The arrows to the left and right of “Select breaker” at the bottomof the dialogue enable you to scroll through the entire list.

Bus-tie breakerIn certain operating conditions, the measurement of the currentthrough the bus-tie breaker has to be blocked. This “end zoneprotection” acts as a backup for a fault between the bus-tiebreaker and the single set of c.t’s being used for both protectionzones. Blocking the bus-tie measurement after a delay excludesit from the evaluation of fault location so that the current leaving


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the protection zone to an apparently external fault can no longerprevent tripping.

Note: The blocking (reclaim) time is determined as follows:Reclaim time = bus-tie breaker operating time + arc extinctiontime + 60 ms(60 ms = total transmission time + safety margin)

Parameter Min. Max. Default Step Unit

Reclaim time 20 300 120 20 ms

Table 5.1 Range of the reclaim time setting for circuit-breakers

Figure 5.6 Details tab in the “Configuration/Circuit-breakers”dialogue


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5.3.4. Configuration/Current transformers

Changing the c.t. labels and ratios:

OverviewAll the c.t’s shown in the single-line diagram are listed in thisdialogue.

Details

Figure 5.7 Overview tab in the “Configuration/Current trans-forer” dialogue

The label in the “Markings” field can be edited. The ratios in the“Transformer ratio” fields are entered in terms of the primary andsecondary rated currents.

Min. Max. Step

Primary [A] L1, L2, L3, L0 50 10000 1

Secondary [A] L1, L2, L3, L0 1 5

5.3.5. Configuration/Voltage transformers

This menu item is only available when v.t’s are installed (seeSection 11 “Options”).


5-9

5.3.6. Configuration/Device structure

The device structure is configured by ABB when engineering thesystem and may only be changed in consultation with ABB.

5.3.6.1. Overview

The central unit and all the bay units are listed together with theirlabels and type. The desired unit is selected by clicking themouse on it.

Figure 5.8 Overview tab in the “Configuration/Device struc-ture” dialogue

5.3.6.2. Details

“Details” shows the function and ABB reference for every type ofmodule. The node ID indicates the assignment of the module onthe process bus.


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Bay unit

Figure 5.9 Details tab for a bay unit in the “Configura-tion/Device structure” dialogue

Central unit

Figure 5.10 Details tab for the central unit in the “Configura-tion/Device structure” dialogue


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The list for the central unit shows whether the modules aremasked or unmasked.Refer to Section 3.2.6.2. “Central unit modules” for further infor-mation.

5.3.7. Configuration/Binary module

This dialogue is used while engineering the protection system toconfigure the binary modules. The data entered is normally pro-vided in the questionnaire filled in by the user. The window hasthree tabs:

• Overview

• Inputs

• Outputs

5.3.7.1. Overview

Figure 5.11 Overview tab in the “Configuration/Binary module”dialogue

The overview tab opens a list with all the binary I/O modules forwhich the following information is given:

• ABB ref. (ABB designation for the bay or central unit)


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• Bay (in which the bay unit is located, user’s label forthe bay)

• Device (label)

• Slot No. (module location in the bay or central unit)

• Module type (designation).

These attributes can only be viewed by clicking on “Select mod-ule” or the arrow keys but not changed.

5.3.7.2. Binary inputs

The overview provides facility for entering the auxiliary supplyvoltage (battery voltage) and viewing the assignment of the bi-nary inputs.The “Details” dialogue enables the opto-coupler inputs to be as-signed to the logical input signals and the event memories to therespective input and output units.

Overview (of input signals for each device)

Figure 5.12 Central unit inputs in the “Configuration/Binarymodule” dialogue


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Figure 5.13 Bay unit inputs in the “Configuration/Binary module”dialogue

The upper part of this dialogue contains a general layout of therespective module. The auxiliary supply voltage for each groupof opto-couplers (with a common pole) is entered below this.All the input signals assigned to the module are listed. The ab-breviations C.i and O.x denote the CLOSE and OPEN auxiliarycontacts on the isolator or circuit-breaker respectively as shownin the properties window.

Deleting a signalThe assignment of a signal is cancelled by marking it in the win-dow and clicking on the “Delete” button.


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Details

Figure 5.14 Details tab for bay unit inputs in the “Configura-tion/Binary module” dialogue

The configuration data of the individual inputs are shown in the“Details” dialogue. These include the contact mode, opto-couplernumber and whether inverted or not inverted.Two inputs should be assigned to an isolator or circuit-breakersignal, one for the OPEN contact and one for the CLOSEDcontact. Where an isolator or a circuit-breaker is only equippedwith a single auxiliary contact, the “One auxiliary contact” modemust be selected.This mode is not recommended because the status of the iso-lator or circuit-breaker cannot be properly monitored with justone auxiliary contact. The signals are configured at the time theprotection system is engineered and are generally not changedsubsequently.

Only the CLOSED signal field is visible when the “One auxiliarycontact” mode is selected. The function of the OPEN signal isachieved by inverting the CLOSED signal. In this case, we rec-ommend connecting the auxiliary contact supply to the corre-sponding input so that its integrity is supervised.


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Minimum input signal durationProvision is made for prolonging the input signals in steps of1 ms.

New signal

Figure 5.15 New input signal button in the “Configuration/Binarymodule” dialogue

The “New signal” button opens a dialogue with a list for selectingand adding a new signal.

Clicking on the arrow button to the right of the signal name fieldopens a list of the signals available for the particular module.Click on “OK” to confirm the choice or on “Cancel” to close thewindow without making a choice. The “Details” dialogue opensautomatically upon clicking on the “OK” button.

The new signal can now be assigned to an opto-coupler and in-verted if necessary.

Caution: To preserve computing capacity, not more than fourinput signals should be assigned to one opto-coupler.


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Central unit signals

Figure 5.16 Assignment of inputs in the “Configuration/Binarymodule” dialogue

Most central unit signals can only be assigned once. There aretwo input signals (“31105_External TRIP BB zone” and“31805_External release BB zone”) per section of busbar (buszone) and the latter must be stated when one of these signals isselected.

Event configuration

Figure 5.17 Configuring events in the “Configuration/Binarymodule” dialogue


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Every signal can be declared to be an event and recorded whenit occurs in one or several event memories (see Section 5.4.8.“Event memory”).

It is possible to configure a signal as an event in either the“Overview” window or the “Details” dialogue. First select the sig-nal (one line) and then click on the “Event config.” button to openthe “Configuration of events” dialogue.

More input fields appear when the “Recording” radio button isselected which enable the event to be recorded on the positiveor negative-going edge or on both edges. The correspondingedge must be selected and a text (up to 20 characters) can beentered for it. If none is entered the system assigns a defaultevent text. At least one event memory in the “Send event to” (=save event in) field must also be selected.

Configuring opto-coupler eventsApart from events generated by function signals, a physical inputcan also be configured as an event. This is of advantage, for ex-ample, when several signals are assigned to a physical input orwhen ambivalent signals from isolators or circuit-breakers needto be recorded. These can be assigned in either the “Overview”or “Details” dialogue.

First select an opto-coupler in the overview window by clickingon it above the signal list (column marked). Now click on the “OCevent config.” button to open the “Configuration of events” win-dow.

5.3.7.3. Binary inputs on the bay units

The following input signals are listed in the same order they ap-pear in the selection list of the operator program on the PC.

11105_External TRIPThis signal is a tripping command received from another protec-tion device (including one in the remote station) and is used forthe REB500 tripping contact to trip faults on a line or a powertransformer.

The “External TRIP” signal generally only effects the circuit-breaker of the feeder concerned. The response for special bus-bar configurations is as follows:


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1½ breaker schemes:Both circuit-breakers connected to the feeder concerned aretripped.

Bypass busbar:An “External TRIP” command that trips circuit-breaker Q0 onfeeder 1 does not isolate the fault if isolator Q7 is closed (bypassmode). Circuit-breaker Q0 on feeder 2 is therefore tripped auto-matically to fully isolate the fault.

Bypass isolator across circuit-breaker:An “External TRIP” command trips the local circuit-breaker Q0on feeder 1. This, however, does not interrupt the fault current,because the bypass isolator Q7 is across the breaker, andtherefore the busbar protection intertrips busbar 3.

Busbar 1

Busbar 2

Busbar 3

Bypass

Feeder 1 Feeder 2

Q0 Q0

Q7

Figure 5.18 Bypass mode


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Busbar 1

Busbar 2

Busbar 3

Feeder 1

Q0 Q7

Figure 5.19 Isolator across the circuit-breaker

11110_External TRIP BB zoneThis input is used when an external signal has to trip an entirebus zone. It is applied to all the bay units of the bus zone.Sections of busbars connected by an isolator trip together (in-tertripping).

11205_Block allA signal applied to this input blocks all the protection functions,“External Trip”, tripping by the busbar protection and intertrippingof the respective bay unit.

11210_Block output relaysAll the output contacts configured for a bay unit are blocked.

11215_Ext. measurement disturbedThis signal is active when invalid analogue values are detected.The busbar protection (i.e. the specific protection zone of thebusbar) and all the local protection functions are blocked. If thedisturbance lasts longer than 400 ms, an event is generated(BBP Minor Error 7).

This input should only be used in special cases and only whenengineering a REB500 system.


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11505_Close command CBThe circuit-breaker close command has to be used for bus-tiebreakers to control the REB500 measuring system. It is alsoused when the end zone protection is configured.

11510...11525_Supervision aux. voltage_xThe supervision of the auxiliary supply is configured when thecompliance of the auxiliary contacts on the isolators with the re-quired switching sequence cannot be guaranteed and for thisreason the “Not CLOSED = OPEN” logic has to be used. Thesesignals ensure that the protection responds correctly should theauxiliary supply to the isolators fail.

This signal is only applicable in the case of “Not CLOSED =OPEN”!

11530_Circuit breaker/Isolator-off/onThe position of a circuit-breaker or an isolator is signalled by oneor two auxiliary contacts. The statuses CLOSED, OPEN and“Isolator alarm” are determined from the positions of the auxiliarycontacts. It is necessary to know the positions of circuit-breakersand isolators in order to:

• generate and image of the busbar configuration

• detect faults in the end zone between an open circuit-breakerand the c.t’s. (CB position).

Refer to Section 3.5 “Technical specification” for the technicalrequirements to be fulfilled.

11605_External release TripProviding they have been configured, a signal applied to this in-put enables tripping by the busbar protection and the intertrip-ping function in the bay unit (AND logic of tripping and enablingsignals). The input has no influence on other protection func-tions.This input can be used in special cases to interlock tripping bythe protection by, for example, an external undervoltage relay.

11610_External resetTripping commands and signals can be configured to latch afterpicking up, in which case they must be reset by applying a signalto this input. It also resets the text display and LED’s on the localcontrol unit. A reset signal resets the entire system.


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11615, 11625, 11635, 11645_Inspection_x-OffThese inspection inputs (x = 1...4) activate the isolator or circuit-breaker inspection mode for the cases 1 to 4.

As with the isolator inputs for the busbar image, two anti-coincident signals can be connected to these inputs. The lastvalid position is maintained and a failure is signalled on the localcontrol panel on the bay unit if both inputs are the same. Shouldonly one inspection signal be available, the “Revision_x-On” inputmust be configured and the signal applied to it (see Section3.4.1.5. “Inspection and maintenance”).

11620, 11630, 11640, 11650_Inspection_x-OnThese inspection inputs (x = 1...4) activate the isolator or circuit-breaker inspection mode.

They must be used should only one inspection input be avail-able.

11655_Maintenance-OffAnti-coincident maintenance input. Refer to the description forthe “Inspection_x-Off” signals.

11660_Maintenance-OnThis input is excited by the maintenance function. It is usedshould only one maintenance signal be available. Refer to Sec-tion 8. “Operation and maintenance” for a detailed description ofthe maintenance function.

11765_General Start DRThis input must be configured as an event and not assigned toan opto-coupler input to achieve a general start of the distur-bance recorder. It is normally configured at the works, but canalso be configured on site using REBWIN.

13205_Block BFPThe operation of the breaker failure protection is blocked for thecorresponding bay unit. When the blocking signal is cancelled,the timers start again at t = 0.

13605_Trip transferredThe circuit-breaker sets this input when it cannot open, for ex-ample, because the air pressure is too low or there is a leak inthe case of GIS (Alarm Stage 3 - Circuit-breaker blocked).


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A tripping signal is then transferred to the adjacent breakers andpossibly the remote station. This function requires that the BFPbe configured.

13705_External Start BFPA signal applied to this input starts the breaker failure protectiontimer (independently of the overcurrent measurement).

13710...13735_Start BFP Lp_xPhase-selective (p = 1...3) starting of the breaker failure protec-tion with two inputs per phase (x = 1 or 2).The breaker failure timer is started by this input signal providingthe current in the respective phase is above pick-up.

13740...13765_Start BFP L1L2L3_xThree-phase starting of the breaker failure protection by six in-puts (x = 1...6). The breaker failure timer is started by a signal at one of theseinputs providing the current in at least one phase is high enough.

14205_Block EFPThe operation of the end fault protection is blocked for the cor-responding bay unit. When the blocking signal is cancelled, thetimers start again at t = 0.

15210_Block OCDTThe operation of the time-overcurrent function is blocked. Whenthe blocking signal is cancelled, the timer starts again at t = 0.

16705...16750_Start DR_xThe disturbance recorder function is started by an external sig-nal applied to one of these 10 inputs (x = 1...10), or they can besimply used for recording purposes. The external signal maycome, for example, from the tripping contact of a line protectionrelay or the starting contact of a time-overcurrent relay. Opto-couplers are configured for these inputs.

17205 Block PDFThe operation of the circuit-breaker pole discrepancy protectionis blocked. The timers start at t = 0 again when the input resets.


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17710 Start PDFThe circuit-breaker pole discrepancy protection is started by anexternal signal applied to this input.

5.3.7.4. Binary inputs on the central unit

The following input signals are listed in the same order they ap-pear in the selection list of the operator program.

31105_External TRIP BB zone (BB zone tripped by externalsignal)A busbar section can be tripped by a signal applied to this input.Up to 32 sections can be addressed. One input can be config-ured for each section. Sections connected by isolators aretripped together (intertripping).

31205_Block allA signal applied to this input blocks all the protection functionsincluding “External Trip” and intertripping.

31210_Block output relaysAll the output contacts configured for the central unit and all thebay units are blocked.

31215_Block IEC master directionREB500 does not transfer any events, error messages, meas-urements etc., to the master station via the station bus IEC60870-5-103 when this input is active.

31505_Accept bus image alarmThis signal acknowledges (resets) an isolator alarm. If it is con-tinuously active, a new isolator alarm is immediately reset.

31805_External release BB zoneThis input enables the tripping signal for a section of busbar(AND gate with tripping and enabling inputs). One of these in-puts can be configured for each busbar section. The entire pro-tection zone surrounding the busbar section is enabled (transfertripping).Sections connected by isolators are also enabled (transfer trip-ping). The input can be used in special cases, for example, tointerlock the tripping signal by an undervoltage relay. This willgenerally delay tripping.


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31810_External resetTripping commands and signals can be configured to latch andwhen they are, they are reset by a signal applied to this input.The same signal also resets the LED’s (alarm and tripping). Thereset signal applies to the entire system.

31815_Ext. superv. in service_1Input for monitoring any fans, external supplies etc. The signal“22010_Alarm” is set in the central unit when this signal changesfrom logical “1” to “0”.

31820_Ext. superv. in service_2Input for monitoring any fans, external supplies etc. The signal“22010_Alarm” is set in the central unit when this signal changesfrom logical “1” to “0”.

31825_Time synchronisationClock synchronisation input. Synchronisation takes place on thepositive edge of a minute impulse. The minute impulse must beat least 20 ms wide.

32205_Block BBPThe entire busbar protection function is blocked.

33210_Block BFPThe operation of the breaker failure protection is blockedthroughout the busbar protection system. When the blockingsignal is cancelled, the timers start again at t = 0 providing thecurrent is higher than setting.

34215_Block EFPThe operation of the end fault protection is blocked throughoutthe busbar protection system. When the blocking signal is can-celled, the timers start again at t = 0 providing the circuit-breakeris open and the current is higher than setting.

35220_Block OCDTThe operation of the time-overcurrent function is blockedthroughout the busbar protection system. When the blockingsignal is cancelled, the timers start again at t = 0.


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36705_General Start DRProviding they have been configured, the disturbance recorderfunctions in all the bay units are started by this input. The signal“General start disturbance recorder” must also be configured inthe bay units.

37205_Block PDFThis signal blocks the operation of the circuit-breaker pole dis-crepancy function throughout the system. The PDF timers startat t = 0 again when this signal resets.

5.3.7.5. Binary outputs

The procedures for configuring binary inputs and outputs arealmost identical. Therefore only the differences are dealt with inthis Section.

Overview (output signals available on each device)

Figure 5.20 Configuring CU outputs in the “Configuration/Binarymodule” dialogue


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Figure 5.21 Overview of BU outputs in the “Configura-tion/Binary module” dialogue

The overview of the BU outputs shows which signals are as-signed to which output relays. A signal can be assigned to up tofour output relays (e.g. BBP TRIP to CR01, 02 and 03) and anoutput relay can be controlled by several signals (e.g. output re-lay CR07 by A1.REMOTE TRIP, A1.BFP REMOTE TRIP and ,A1.EFP REMOTE TRIP).

For reasons of safety, it is impossible to mix tripping commandsand signals, i.e. tripping commands can only be combined withtripping commands and control signals with control signals.

Tripping commands:

• 21105_EXTERNAL TRIP

• 21110_TRIP

• 23105_BFP TRIP

• 25105_OCDT TRIP

• 27105_PDF TRIP

The remaining signals and all the CU signals are control signals.


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Details

Figure 5.22 Details of CU outputs in the “Configuration/Binarymodule” dialogue

Figure 5.23 Details of BU outputs in the “Configuration/Binarymodule” dialogue

This dialogue applies for three functions or input fields.


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Signal delayEvery output signal can be configured either to latch (until re-set by a signal) or to have a defined reset delay. A reset delaycan be entered in the field “t” and can be incremented byclicking with the mouse.

Blocking output signals throughout the systemIn the case of all the output signals being blocked by the self-supervision function or a signal applied to the blocking CU orBU input “Block output relays”, the statuses of the selectedoutput signals cannot change. This setting determineswhether a signal is really blocked of is generated anyway.

Relay outputThe current signal is assigned to the output relays withchecked check boxes. Other signals of the same type (trip-ping command or control signal) may also be assigned to thesame relay.

Unavailable output relays (grey) already have signals of theother type assigned to them. The remaining relays are avail-able for other signals.

New signalSame as for the binary inputs (see Section 5.3.7.3. “Binary in-puts on the bay units”).

Central unit signalsMost of the CU signals only occur once. There is an outputsignal “Trip BB zone” for each section of busbar (bus zone),therefore the respective zone must be given when selectingthis signal.

DeleteSame as for the binary inputs (see Section 5.3.7.3. “Binary in-puts on the bay units”).

Configuring eventsAn output relay event is configured in the same way as an in-put signal event. An event is generated when the output sig-nal is set and reset.


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Configuring output relay eventsAn event is generated when an output relay picks up or re-sets, i.e. this type of event takes any reset delay that hasbeen set or blocking by another signal into account.Select an output relay in the overview dialogue first by clickingon its label above the signal list (its column is then high-lighted). Now open the event configuration dialogue by click-ing on the “CR event config.” button.

As in the case of the binary input signals in Section 5.3.7.2., thebinary output signals are configured at the works.

5.3.7.6. Binary outputs on the bay units

The following output signals are listed in the same order theyappear in the selection list of the operator program.

21105_EXTERNAL TRIPTripping command generated by the external input 11105_EX-TERNAL TRIP.

21110_TRIPTripping command generated by the intertripping function (BBP,BFP t2 etc.).

21115_Remote TRIPTripping command issued to the remote station by the functionsbusbar protection, breaker failure protection, end fault protectionand the EXTERNAL TRIP command. In the case of a 1½breaker scheme, the signal “Remote TRIP” is dependent on thebusbar protection, breaker failure protection and end fault pro-tection, i.e. remote tripping can only take place if the breakerfailure function is configured.

Remote tripping can only take place if a fault cannot be clearedby the circuit-breaker in the bay concerned. This applies in thefollowing cases:

• 1½ breaker schemes

• Bypass operation with the bus tie breaker being used for afeeder

• Circuit-breaker bypassed by an isolator


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21305_TripSignals tripping by the bay unit and can be set by any of theprotection functions.

21405_All blockedSignals that all the protection functions including “External Trip”and intertripping are blocked.

21410_Output relays blockedAll the output contacts configured in the bay unit concerned areblocked.

21805_In serviceSignal set by the diagnostic function that shows that a bay unit isoperational and standing by.

21810_Loss of supply voltageThis signals a failure of the isolator auxiliary voltage (“Super-vision aux. voltage_x”) in the bay unit.

21815_Inspection/maintenanceSignals that an inspection or maintenance input is set on the bayunit.

22405_BBP blockedSignals that the busbar protection function is blocked.

23105_BFP TRIPTrip generated by the breaker failure protection.

23110_BFP remote TRIPTripping command issued to the remote station by the breakerfailure protection. This signal can be assigned to an output con-tact by the signal “Remote TRIP”.

23305_BFP trip t1Signals tripping by the breaker failure protection after time 1.

23310_BFP trip t2Signals tripping by the breaker failure protection after time 2.


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23315_BFP trip L1Signals that the breaker failure protection detected a fault onphase L1 and has tripped.



23330_Trip transferredSignals that tripping has been redirected. The input “Trip trans-ferred” must be set and a trip command must be active.

23335_Trip by BFPSignals that the breaker failure protection has issued an inter-tripping command.

23405_BFP blockedSignals that the breaker failure protection is blocked (either thebay or the whole system).

24105_EFP remote TRIPTripping command issued by the end fault protection.

24305_EFP tripSignals that the end fault protection has tripped.

24405_EFP blockedSignals that the end fault protection is blocked (either the bay orthe whole system).

25105_OCDT TRIPTripping command issued by the time-overcurrent function.

25405_OCDT blockedSignals that the time-overcurrent protection is blocked (either thebay or the whole system).


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26805_DR readySignals that the disturbance recorder is standing by.

26810_DR memory fullSignals that the disturbance recorder memory is full.

26815_DR recordingSignals that the disturbance recorder is in the process of re-cording.

26820_DR record availableSignals that disturbance records are available.

27105_PDF TRIPTripping command by the circuit-breaker pole discrepancy func-tion.

27305_PDF TripSignals tripping by the circuit-breaker pole discrepancy function.

27405_PDF blockedSignals that the circuit-breaker pole discrepancy function isblocked.

5.3.7.7. Binary outputs on the central unit

All the outputs generated by the central unit are signals for con-trol or information. They are listed in the same order they appearin the selection list of the operator program.

41305_Trip BB zone (busbar designation)Signals which busbar sections have been tripped. An output canbe configured for each busbar section which is then corre-spondingly designated. There are as many output relays asthere are busbar zones and where the number of busbar zonesis high, a second BIO module is needed.

41310_Trip transferredSignals that tripping has been redirected by the input “Triptransferred” on a bay unit.


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41405_All blockedSignals that all the protection functions including “External Trip”,busbar protection and intertripping are blocked.

41410_Output relays blockedAll the output contacts that are configured are blocked.

41505_Isolator alarmThis signal indicates that at least one isolator or circuit-breaker isnot reporting a defined position (neither CLOSED nor OPEN). Itis issued at the end of the set time delay and is reset by the in-put “Acknowledge isolator alarm”, respectively set again by thenext isolator alarm.

41805_AlarmThis signal is set in the following cases:

• Supply failure

• Failure or disturbance of a central unit module

• Failure of the communication with a bay unit

• Failure of a bay unit

• Failure of a bay unit function

• Error when refreshing the data in the protection system

• Communication error in the central unit

• “Ext. superv. in service_1/2” not set.

41805_In serviceSignal set by the diagnostic function that shows that the centralunit is operational and standing by.

41815_Diff. current alarmThe differential current of a protection zone exceeded the setalarm level during the preset interval.

41820_Loss of supply voltageSignals the failure of the isolator auxiliary supply on a bay unit(“Supervision aux. voltage_x”). It is used in conjunction with “NotOPEN = CLOSED”.


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41825_Inspection/maintenanceSignals that an inspection or maintenance input is set on one ofthe protection units.

41830_Switch inhibitThis signal appears together with “Isolator alarm”. No switchingof the primary system may take place as long as this signal isactive, because the image of the primary system in the protec-tion would not then correspond to the actual situation.

41835_Test generator activeSignals that the test generator is active, i.e. the test generator isin use somewhere on the busbar protection system.

42305_BBP tripSignals that the busbar protection has tripped.

42310_BBP trip L0Signals that a fault was detected on phase L0 and the busbarprotection has tripped.




42405_BBP blockedSignals that the busbar protection is blocked.

43305_BFP trip t1Signals that the breaker failure protection tripped in time step 1.

43310_BFP trip t2Signals that the breaker failure protection tripped in time step 2.


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43405_BFP blockedSignals that the breaker failure protection is blocked (either abay unit or the entire system).

44305_EFP tripSignals that the end fault protection has tripped.

44405_EFP blockedSignals that the end fault protection is blocked (either a bay unitor the entire system).

45305_OCDT tripSignals that the time-overcurrent protection has tripped.

45405_OCDT blockedSignals that the time-overcurrent protection is blocked (either abay unit or the entire system).

45805_OCDT startSignals that one of the feeder time-overcurrent functions haspicked up.

47305_PDF TripSignals tripping by the circuit-breaker pole discrepancy function.

47405_PDF blockedSignals that the circuit-breaker pole discrepancy function isblocked (either just the bay or the whole system).

5.3.8. Configuration/Disturbance recorder

5.3.8.1. Analogue inputs

The currents measured by the four analogue inputs are alwaysrecorded. The four voltage inputs may only be recorded provid-ing they have been licensed and engineered (optional).

The recording time is doubled if the voltage channels are not ac-tivated.


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The dialogue has three tabs:

• Configuration

The configuration dialogue shows a bay unit together with itsrecording mode and signals.

• Overview

The overview shows all the bay units and their basic distur-bance recorder configurations. A bay unit is selected byclicking on it with the mouse.

• License status

The license dialogue lists all the bay units and the duration ofrecording.

5.3.8.2. Recording

The following disturbance recorder settings can be made:

• Sampling frequency600/720 Hz, 1200/1440 Hz or 2400/2880 Hz. The maximum re-cording time is automatically adjusted to suit.

• Number of records ‘n’The maximum recording time available is divided by this set-ting into ‘n’ equal time periods. For example, assuming 3 rec-ords have to be made and a maximum recording time of 6seconds, 3 records of 2 seconds each can be recorded.

• Acquisition time This setting determines how much time before the triggeringpoint is included in the record.The total recording time is at least 0.5 s. Of this, at least 0.2 sare pre-event time and therefore at least 0.3 s post-eventtime.

• In the event of overflowResponse of the disturbance recorder should the memoryoverflow.

5.3.8.3. Binary channels

All binary signals (input, output or internal signal) can be re-corded. For this purpose, they must be configured for recordingand identified by their signal labels.


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The name is used for identification in the COMTRADE file duringrecording. The user has the possibility to edit the labels as nec-essary.

Figure 5.24 Configuration and recording tabs in the “Configura-tion/Disturbance recorder” dialogue

5.3.8.4. Signals

Up to 32 binary signals per bay can be selected for recording. Ofthese, up to 12 can be configured to trigger the start of record-ing. Triggering can take place on the lagging or leading edge ofa signal. If “both edges” is selected, both lagging and leadingedges are active.

Once recording has been started, the complete recording periodthat has been set is recorded.

In addition to the normal bay unit binary signals, there are up toten general purpose input signals that can be configured for re-cording and for triggering the disturbance recorder.


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Figure 5.25 Configuration and signals tabs in the “Configura-tion/Disturbance recorder” dialogue

Figure 5.26 Overview tab in the “Configuration/Disturbance re-corder” dialogue

Only the bay units engineered for the station are available forconfiguration.


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Figure 5.27 License status tab in the “Configura-tion/Disturbance recorder” dialogue

Trigger operation

Recording commences when at least one of the triggering con-ditions is fulfilled. The trigger then remains disabled until the re-cord has been completed and is then enabled again. You musttherefore set the recording period such that all the signals youwant to record can be recorded.

Caution: The trigger inputs are scanned every 16 ms. A triggersignal must therefore be at least 16 ms long to be certain that itwill be detected.


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5.3.9. Configuration/CB inspection

The plant inspection and maintenance records are displayed.

Figure 5.28 Overview tab in the “Configuration/CB inspection”dialogue


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5.4. Settings and calculations

“Settings” menuThis menu accesses the system and protection function pa-rameters and the corresponding setting instructions are givenbelow.

5.4.1. Rated frequency (not adjustable)

The rated frequency of the protection system (50 or 60 Hz) isentered while engineering the system. It is recorded in the report“General plant data” (see Section 4.5.36. “Tools/Reports”).

5.4.2. Settings/System response

5.4.2.1. System response to a differential current alarm

After selecting the menu item “System response” in the “Set-tings” menu, a dialogue opens that permits you to select how thesystem should react in the event of a differential current alarm:

• Continue in operationThe busbar protection continues to function regardless of thedifferential current alarm.

• Block busbar protectionOperation of the entire busbar protection is blocked.

• Selective block busbar protection (preferred)Operation of the busbar protection is only blocked for thesection of busbar (protection zone) concerned.

5.4.2.2. System response to an isolator alarm

the same dialogue also permits the response of the system to bedetermined in the event of an isolator alarm:

• Continue in operationThe busbar protection continues to function regardless of theisolator alarm.

• Block busbar protectionOperation of the entire busbar protection is blocked.


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• Selective block busbar protection and intertripping (preferred)Operation of the busbar protection is only blocked for thesection of busbar (protection zone) concerned.

Figure 5.29 “Settings/System response” dialogue

The radio buttons enable the desired response of the system inthe event of a differential current or an isolator alarm to be se-lected. The setting for the isolator operating time applies for allthe isolators and switches in the system.

The protection can be configured such that in the event of a dif-ferential current or an isolator alarm, only the protection zone di-rectly involved is blocked (selective blocking).

The setting for “Remote trip impulse width” limits the duration ofa transfer tripping signal sent to the remote end of the line (seeSection 5.4.2.4. “Remote trip impulse width”).

5.4.2.3. Isolator alarm delay

The busbar protection REB500 has a common alarm circuit andtimer for monitoring the operation of all the isolators and bus-tiebreakers.

Note: The time delay must be set longer than the slowest iso-lator operating time.


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5.4.2.4. Remote trip impulse width

The busbar and where configured, the breaker failure and endfault protection functions can send an intertripping signal to aremote station via PLC or optical fibre communication channel.The duration of the impulse usually has to be limited.


Remote trip impulsewidth

100 2000 200 10 ms

Table 5.2 Setting range of the remote trip impulse width

Note: The typical duration of the remote tripping impulse is200 ms.


5-44

5.4.3. Busbar protection (settings and calculations)

The following parameters can be set using the REBWIN opera-tor program:


IKmin

Op. char. ‘L1, L2, L3’500 6000 1000 100 A

kOp. char. ‘L1, L2, L3’

0.7 0.9 0.80 0.05

Differential current alarmOp. char. ‘L1, L2, L3’

5 50 10 5 % IKmin

Delay(differential current alarm)Op. char. ‘L1, L2, L3’

5 50 5 5 s

IKmin

Op. char. ‘L0’100 6000 300 100 A

kOp. char. ‘L0’

0.7 0.9 0.80 0.05

Differential current alarmOp. char. ‘L0’

5 50 10 5 % IKmin

Delay(differential current alarm)Op. char. ‘L0’

5 50 10 5 s

Table 5.3 Busbar protection settings


5-45

Figure 5.30 “Settings/System response” dialogue

The operating characteristic shown in the above dialogue onlyapplies for the restrained current amplitude comparison algo-rithm. There are no settings for the phase comparison algorithm.


Overcurrent check inactive

Setting(overcurrent check,if active)

0.1 4,0 0.7 0.1 IN

Table 5.4 Settings for the overcurrent check feature

The overcurrent check feature is a local bay function that onlyinfluences intertripping commands (i.e. busbar protection tripsand intertripping by the central unit) and tripping by the breakerfailure protection.

L1, L2, L3 operating characteristicThis dialogue is for entering the parameters applicable to thephase fault operating characteristic. To change a value, click onthe arrow button to the right to open a list of possible settingsand then click on the desired value. Click on the “OK” or “Apply”


5-46

button to confirm the setting, or on “Restore” or “Cancel” to re-ject it.

L0 operating characteristicThe procedure for setting the ground fault characteristic is thesame as for phase faults.This dialogue is only available providing a neutral current meas-urement has be configured.

5.4.3.1. Restrained amplitude comparison — IKmin and k

The ‘restrained amplitude comparison’ algorithm detects an in-ternal fault when the settings for IKmin and k are exceeded. Atripping command is only issued, however, providing the phasecomparison function detects an internal fault at the same time.

Note: The pick-up setting for the fault current (IKmin) must beless (80 %) than the lowest fault current that can occur on thebusbars (IKMS). There is a risk of the protection being too insen-sitive at higher settings.

Providing the minimum fault current (IKMS) is high enough, IKminshould be set higher than the maximum load current.

If the c.t’s saturate at the minimum fault current, the feeder cur-rents have to be reduced by a factor cR. The corrected currentvalues form the basis for calculating the setting for IKmin. The re-duction factor cR is calculated as follows:

For a power system time constant TN ≤ 120 ms:

C eR

II nK

N= + ⋅−

⋅ ⋅0 45 0 55 0 3. . . '

For a power system time constant 120 ms < TN ≤ 300 ms:

C eR

II nK

N= + ⋅−

⋅ ⋅0 2 0 8 0 5. . . '

In both cases:

n n P PP P

N E

B E' = ⋅ +

+

where CR reduction factor due to the power system time con-stant


5-47

IK in this case, the vectorial sum of feeder fault andload currents for an internal fault

IN c.t. rated current

TN power system time constant

n rated overcurrent factor

n' effective overcurrent factor

PB power consumption of the burden at rated current

PE c.t. losses

PN c.t. rated power

5.4.3.2. Application example

The minimum busbar fault current is 1300 A and is supplied bytwo feeders. The time constant TN of the power system is 80 ms.

Feeder 1:Contribution to minimum fault current: 800 A

C.t’s: Ratio: 200 A/1 AClass: 5P10PB: 6 VAPE: 5 VAPN: 10 VA

6.13VA5VA6VA5VA1010'n =

++⋅=

66.0e55.045.0C 6.13A2003.0A800

R =⋅+= ⋅⋅−

Feeder 2:Contribution to minimum fault current: 500 A

C.t’s: Ratio: 400 A/1 AClass: 5P20PB: 6 VAPE: 8 VAPN: 20 VA

n VA VAVA VA

'= ⋅ ++

=20 20 86 8

40


5-48

95.0e55.045.0C 40A4003.0A500

R =⋅+= ⋅⋅−

Reduced fault current IKR:

IKR = 800 A · 0.66 + 500 A · 0.95 = 1003 A

IKmin setting:

IKmin = 1003 A · 0.8 = 802 A

The factor k is normally set to 0.80. Numerous test on a networkmodel have shown this setting to be the most favourable.

Figure 5.31 Operating characteristic of the restrained amplitudecomparison function

During a through-fault and normal operation, it is impossible forthe differential (operating) current to be higher than the restraintcurrent.

Other parameters may also influence the setting in extremecases and these are explained in the following examples.


5-49

5.4.3.3. Busbar with just two feeders

IB IB

Feeder 1 Feeder 2

Busbar

Figure 5.32 Busbar with two feeders

Assuming a fault on the c.t. secondary of feeder 1 or 2 (c.t. openor short-circuit), false tripping can be prevented by settingswhich satisfy the inequality:

IKmin > IBThe fault current setting IKmin must be higher than the load cur-rent IB.

5.4.3.4. Busbar with several feeders

Feeder 2 Feeder 3

Busbar

IB1=2 kA

Feeder 1(infeed)

IB2=1.7 kA IB3=0.3 kA

Figure 5.33 Busbar with three feeders

a) C.t. circuit fault on feeder 1The c.t. circuit fault simulates a fault on the busbars with a cur-rent ∆I = IB2 + IB3 = 2 kA. False tripping can be avoided with asetting which satisfies the inequality:

IKmin > 2 kA (e.g. the next higher setting 2.1 kA)


5-50

b) C.t. circuit fault on feeder 2The c.t. circuit fault in this case simulates a fault on the busbarswith a fault current ∆I = IB2 - IB3 = 1.7 kA and the value calcu-lated for the quotient k becomes:

k II

I II IB B

B B= =

−+

= =∆ 1 3

1 3

172 3

0 74..

.

False tripping can thus be avoided with settings for IKmin and/or kwhich satisfy the inequalities:

IKmin > 1.7 kA

and/or

k > 0.74

c) C.t. circuit fault on feeder 3This case corresponds to case b), but the values for ∆I and k arelower:

∆I = IB1 - IB2 = 0.3 kA

k I II IB B

B B=

−+

= =1 2

1 2

0 33 7

0 081..

. i.e. k « 0.7

A c.t. circuit fault under normal load conditions cannot causefalse tripping.

d) Influence of the phase comparison functionTripping can only take place when both functions (restrainedamplitude comparison and phase comparison) detect an internalfault. The decision reached be the phase comparison function istherefore of no consequence in the cases illustrated in this sec-tion.

e) SummaryConsidering case a), the pick-up setting for the fault current inthe example given must be:

IKmin > 2 kA

This is the only setting which will prevent tripping in the case ofa).


5-51

Both settings, k = 0.80 and IKmin > 1.7 kA prevent tripping incase b).

A dangerous setting is impossible in case c).

Assuming a minimum fault current higher than 2.1 kA (see casea)), the settings for the above example become:

IKmin > 2.1 kA

k = 0.80

For a minimum fault current lower than 2.1 kA or even lowerthan the maximum load current of 2 kA, the setting of IKmin canresult in both a failure of the protection to trip when it should or afalse trip:

• With a setting of IKmin > 2 kA, the protection in the above ex-ample would not detect a minimum fault current of 2 kA (ex-cluding a c.t. fault).

• With a setting of IKmin < 2 kA, a fault in the c.t. circuit accord-ing to case a) would cause a false trip.

The best solution in this situation is to set IKmin to 80 % of theminimum fault current (IKMS).

5.4.3.5. Busbar fault with through current

In certain circumstances, it is possible for currents to flow awayfrom the busbars during a busbar fault. Two examples of this arediscussed below.

a) Through current

Busbar fault

IRIK3IK2IK1

Figure 5.34 Busbar fault with through current IR

∆I I I I I I IK K K R K R= + + − = −1 2 3

I I I I I I IK K K R K R= + + + = +1 2 3


5-52

k II

I II IK R

K R= =

−+

∆Σ

The busbar protection will only trip providing the total fault cur-rent (IK) exceeds a certain minimum:

k 0.9 0.85 0.8 0.75 0.7

IK 19 12.4 9 7 5.7 × IR

Table 5.5 Minimum internal fault current to ensure tripping

For the phase comparison function not to prevent tripping, thelow current check for including feeder currents in the phasecomparison (see Section 3.3.2.2. “Phase comparison”) must beset higher than the through current IR. This must be determinedwhen engineering the scheme.

An alternative is to disable the phase comparison function whichalso must be determined when engineering the scheme.

b) Loop current

Busbar fault

IK3IQIQIK2IK1

Figure 5.35 Busbar fault with a loop current

∆I I I I I I IK K K Q Q K= + + + − =1 2 3

I I I I I I I IK K K Q Q K Q= + + + + = +1 2 3 2

k II

II I

K

K Q= =

+∆

Σ 2


5-53

The busbar protection will only trip providing the total fault cur-rent (IK) exceeds a certain minimum:

k 0.9 0.85 0.8 0.75 0.7

IK 18 11.4 8 6 4.7 × IQ

Table 5.6 Minimum internal fault current to ensure tripping

For the phase comparison function not to prevent tripping, thelow current check for including feeder currents in the phasecomparison (see Section 3.3.2.2. “Phase comparison) must beset higher than the loop current IQ. This must be determinedwhen engineering the scheme.

A alternative is to disable the phase comparison function whichalso must be determined when engineering the scheme.

5.4.3.6. Differential current alarm setting

The setting for the differential current alarm is entered as a per-centage of the minimum fault current setting IKmin.


Differential currentalarm

5 50 10 5 %

Table 5.7 Differential current alarm setting range

Note: A typical setting is 10 %.


5-54

5.4.3.7. Differential current alarm delay setting

Should the differential current alarm pick up, alarm is not actuallygiven until the set time delay has expired.


Time delay 2 50 2 1…5 s

Table 5.8 Time delay setting range for the differential currentalarm

Note: A typical setting is 5 s.

5.4.3.8. Neutral current supervision (operating characteristic L0)

This setting is only available if it is enabled (see Section 11. “Op-tions”).

5.4.3.9. Phase comparison

No settings have to be made using the REBWIN operator programfor the phase comparison algorithm. The settings for this functionare determined when engineering the scheme for a particular ap-plication. The parameters involved are the operating angle ϕmaxand the two minimum current settings (L1, L2, L3 and L0) for the in-clusion of a feeder in the evaluation.

5.4.3.10. Overcurrent check for enabling tripping

The tripping of a circuit-breaker by the busbar protection can alsobe made dependent on whether the feeder in question is conduct-ing a certain minimum current. The setting thus applies to individualbay units (see Table 5.4)

If the overcurrent check is not set for a feeder, any tripping com-mand (“21110_TRIP”) passes to the circuit-breaker without acheck being made that the feeder is actually conducting current.


5-55

5.4.3.11. Undervoltage check for enabling tripping

See Section 11.

5.4.4. Breaker backup protection

This function only appears providing it is enabled (see Section 11“Options”).

5.4.5. End fault protection


5.4.6. Time-overcurrent protection


5.4.7. Circuit-breaker pole discrepancy function


5.4.8. Event memory

The busbar protection includes an event memory for each individ-ual unit (central unit and bay units) in which changes in the statusesof binary signal are recorded. The event memories have a capacityfor 100 events in bay units and 1000 events in the central unit. Theuser can select whether the oldest event should be overwritten (ringregister) or no further events recorded when the memory is full.

A time stamp (date and time with an accuracy of 1 ms), a text de-fined using the operator program and a status (set or reset) areattached to every event. Individual texts can be entered for eachstatus.

Generally, one event is configured for every input and output, butevents can also be assigned to opto-coupler inputs or relay out-puts.

When a PC running the operator program is connected, events canbe uploaded from the protection to the PC. The events stored in thecentral unit can only be read when connected to the central unit and


5-56

the events stored in bay units when connected to either the centralunit or the respective bay unit.

Events that are no longer needed in the PC can be deleted eitherindividually or collectively in marked groups.

Figure 5.36 “Settings/Event memory” dialogue


6-1

June 2000

6. Erection and installation

6.1. General ....................................................................................6-2


6.3. Checking the shipment.............................................................6-3

6.4. Erection....................................................................................6-36.4.1. Material required ......................................................................6-36.4.2. Relay location and ambient conditions.....................................6-36.4.3. Installation in cubicles ..............................................................6-46.4.4. Decentralised installation in switch panels ...............................6-5

6.5. Installation................................................................................6-56.5.1. Grounding guidelines ...............................................................6-56.5.1.1. Cubicle grounding ....................................................................6-66.5.1.2. Grounding principles for bay units............................................6-86.5.1.3. Mounting in an open frame ......................................................6-86.5.1.4. Grounding straps (copper braid) and their fittings....................6-96.5.2. Wiring.....................................................................................6-106.5.2.1. External wiring........................................................................6-106.5.2.2. Internal wiring.........................................................................6-106.5.3. Screening...............................................................................6-126.5.3.1. Cable screens ........................................................................6-126.5.3.2. Terminating cable screens .....................................................6-126.5.3.3. Additional grounding points along cables...............................6-136.5.4. Laying optical fibre cables......................................................6-14


6-2

6. Erection and installation

6.1. General

The busbar protection equipment must be shipped, stored andinstalled with the greatest care.

Install the cubicles such that there is adequate access from thefront and the rear for maintenance or additions.

Air must circulate freely around the equipment. Observe all therequirements regarding place of installation and ambient condi-tions given in Section 3 “Technical Specification”.

Take care that the external wiring is properly brought into theequipment and terminated correctly and pay special attention togrounding. Strictly observe the corresponding guidelines con-tained in this section.


Danger: If parts of the station are in operation, be sure to takeall the necessary safety precautions to prevent electrical shock.

Caution: If parts of the station are in operation, be sure to inter-rupt the tripping circuits to avoid unintentional operation of therespective circuit-breakers during erection and commissioning.

Note: Allow for the weight marked on the crates and packing ofthe individual units when transporting and lifting the protectionequipment.

Note: Cubicles which have been removed from their packingmay only be lifted by the lugs on the top.


6-3

6.3. Checking the shipment

Upon receipt, check that the consignment is complete. Informyour local ABB agent or representative should discrepancies befound in relation to the delivery note, shipping documents or or-der.

Visually check all the items when unpacking. Should any trans-port damage be found, lodge a claim in writing with the last car-rier without delay and inform ABB.

If the protection equipment is not going to be installed immedia-tely, all items must be stored in a closed room in their originalpacking. The humidity should not exceed 95 % at a maximumtemperature of +40 °C; the permissible storage temperaturerange in dry air is -40 °C to +85 °C.

6.4. Erection

6.4.1. Material required

All the small parts needed are included in the installation kit.

A suitable drill and spanners are required to secure the cubiclesto the floor using the plugs provided.

6.4.2. Relay location and ambient conditions

The place of installation should permit easy access especially tofront of the device, i.e. to the optical fibre cable connector andthe local control unit.

There should also be free access at the rear of the equipmentfor additions and replacement of electronic modules.

Since every piece of technical equipment can be damaged ordestroyed by inadmissible ambient conditions,

• the location should not be exposed to excessive air pollution(dust, aggressive substances)

• severe vibration, extreme changes of temperature, highlevels of humidity, surge voltages of high amplitude and shortrise time and strong induced magnetic fields should be avoi-ded as far as possible

• air must be allowed to circulate freely around the equipment.

The equipment can in principle be mounted in any attitude, but itis normally mounted vertically (operation of the local control unitand visibility of markings).


6-4

In all other respects, observe the limits and ranges given in Sec-tion 3 “Technical specification”.

6.4.3. Installation in cubicles

In the case of equipment supplied in cubicles, place the cubicleson the foundations that have been prepared as shown in the in-stallation diagram. Take care while doing so not to jam or other-wise damage any of the cables that have already been installed.Secure the cubicles to the foundations as shown in the drawing.

Figure 6.1 Front view and view with the hinged equipmentframe swung out of a REB500 busbar protectioncubicle


6-5

Figure 6.2 Cubicle layout for 1, 2 and 3 cubicles(W = 800 mm, D = 800 mm) with floor bolt di-mensions

6.4.4. Decentralised installation in switch panels

Where the busbar protection equipment is to be mounted inswitch panel cut-outs, the racks and switch panels must bemounted first and then the busbar protection units inserted intothe cut-outs and secured (installation kit).

6.5. Installation

6.5.1. Grounding guidelines

Switching operations in HV installations generate transientovervoltages on instrument transformer and control signalcables. There is also a background of electromagnetic RF fieldsin electrical installations that can induce spurious currents in thedevices themselves or the leads connected to them.

All these influences can influence the operation of electronicapparatus.

On the other hand, electronic apparatus can transmit interfe-rence that can disrupt the operation of other apparatus.

In order to minimise these influences as far as possible, certainstandards have to be observed with respect to grounding, wiringand screening.

Note: All these precautions can only be effective if the stationground is of good quality.


6-6

6.5.1.1. Cubicle grounding

6.5.1.1.1. Mechanical design

The RF impedance from the location of the various modules inthe cubicle to the cubicle ground must be low.

There must therefore be a good electrical contact between themetal parts of the cubicle such as side plates, blanking platesetc., and the frame and base of the cubicle. The contact surfa-ces must not only be good electrical conductors, they must alsobe corrosion-proof so that long-term good electrical conductivityis preserved.

Non-observance of these conditions can result in the cubicle orparts of it resonating at certain frequencies, which increases theinterference transmitted by the units in the cubicle and can lowertheir immunity to electrical interference from outside.

6.5.1.1.2. Grounding a single cubicle

The moving parts of a cubicle such as the doors (front and rear)or hinged frame must be connected to the cubicle structure bythree copper braid straps (see Figure 6.3 “Cubicle groundingprinciples”).

Mount cubicle ground rail close to bottom of cubi-cle

Station ground

Rack

Bay unit

Door or hinged frame

Copper braid, width ≥≥≥≥ 20 mm, cross-section ≥≥≥≥ 16 mm2 Braid lug, i.e. good electrical connection

Figure 6.3 Cubicle grounding principles


6-7

The cubicle ground rail is connected to the station ground by acopper braid strap (see Section 6.5.1.4 “Grounding straps (cop-per braid) and their fittings”).

If the distance to the station ground exceeds 5 m, two strapsmust be run in parallel as closely as possible to each other.

6.5.1.1.3. Grounding principles for adjacent cubicles

Where cubicles are standing next to each other (less than 1 mapart), observe the following additional conditions (example with2 cubicles).

Cubicle

Cubicle ground rail

Station ground

Figure 6.4 Grounding principles for two adjacent cubiclesThe ground rails in the two cubicles are connected together andeach one individually connected to the station ground. Theground rails of cubicles that are more than 1 m apart do nothave to be connected.

The cubicles of a suite of several cubicles are also connectedtogether and each one individually connected to the stationground.


6-8

6.5.1.2. Grounding principles for bay units

The grounding straps of racks and modules may be connectedon either the left or right, but whichever the case, they should beas short as possible.

* Pre-assembled grounding bolt ** A copper braid strap can be attached at one of these positions.

Figure 6.5 Grounding individual bay units

6.5.1.3. Mounting in an open frame

An open frame must be electrically conducting, corrosion-proofand properly connected to the station ground (see Figure 6.6).

Station ground

Electricallyconductingconnection

Electricallyconductingconnection

Electricallyconductingconnectionon bothsides

Mounting plate

Openframe

Cover

Figure 6.6 Methods of grounding units in open frames(front view, semi-flush and surface mounting)


6-9

The contact surfaces between mounting plates or covers andthe frame must be electrically conducting, i.e. neither contactsurface may be painted and the contact area must be corrosion-proof (e.g. galvanised).

The units must be grounded directly to the rack frame as shownin Figure 6.6 if the contact surfaces are poor conductors or tothe mounting plate as shown in Figure 6.10 in Section 6.5.3“Screening“ providing the surfaces are good conductors.

The units must be grounded such that the grounding straps areas short as possible.

As described in Section 6.5.1.1.2. “Grounding a single cubicle”,a second grounding strap must be run in parallel if the stationground is more than 5 m away.

6.5.1.4. Grounding straps (copper braid) and their fittings

The interference currents conducted by the ground connectionsare of high frequency and as a result of the skin effect, only thepart of the ground straps near the surface is of consequence.

Tinned copper braid is therefore used for the ground straps andnot copper rod, because the cross-section of an equivalent rodwould be much greater.

Data of copper braid straps: Width ≥ 20 mmCross-section ≥ 16 mm2

(necessary for protection grounds)

Both ends of the straps must be fitted with lugs suitable for theconnecting to ground bolts.

The surfaces in contact with the lugs must be electrically con-ducting and corrosion-proof.

Copper braid Cable lug

Contact surface

Ground bolt

Figure 6.7 Grounding straps and their termination


6-10

Caution: In the case of aluminium contact surfaces, a cupaldisc (copper-plated aluminium) must be fitted between the lugand aluminium to prevent corrosion.

6.5.2. Wiring

6.5.2.1. External wiring

The external wiring includes all the connections between theprimary system plant and the cubicle, rack or device terminals.

The corresponding cables should be run in metal cable ductsthat are connected at several points to the station ground.

The external wiring falls into the following groups:

• instrument transformer leads

• auxiliary supply connections

• binary inputs and outputs.

Experience as shown that most interference is induced in theinstrument transformer leads and therefore these should berun in separate cable ducts away from the other cables.

Caution: The instrument transformer lead in GIS stations mustbe screened (see Section 6.5.3). This is also to be recommen-ded in the other kind of stations.

6.5.2.2. Internal wiring

The internal wiring comprises the connections between the cu-bicle or rack terminals and the terminals on the devices. Thiswiring should be kept as short as possible especially in openframes.

As described in Section 6.5.2.1. “External wiring”, it is recom-mended to separate the instrument transformer leads from theother cables, i.e. they should not be run in the same cable ductsor loom. To reduce the risk of parallel coupling, cables may alsobe crossed at right-angles (see Figure 6.8 “Wiring of two bayunits to be performed by the customer”). The minimum cross-coupling occurs when cables cross at right angles.

Pre-wiring non-defined inputs is not permissible.


6-11

Terminal blocks

C.t. leads

C.t. leads

Binary inputs and outputsAux. supply

Crossed at right angles

Figure 6.8 Wiring of two bay units to be performed by thecustomer


6-12

6.5.3. Screening

6.5.3.1. Cable screens

Cables have braided screens with a cover ratio of more than80 %.

6.5.3.2. Terminating cable screens

Cable screens must be terminated such that the entire circumfe-rence of the screen is in contact with ground. Cable screensmust be grounded at both ends.

Caution: The screening effect is inadequate in industrial instal-lations if the cable screen is grounded by a wire soldered to it.

The screens of cables can be grounded best if the cables entercubicles via cable glands. Where this is not possible, proceed asillustrated in Figure 6.9, taking care that that the cable screensare grounded inside the cubicle as closely as possible to theentrance.

In order to connect the screen to ground, remove a suitablelength of the insulation, push the exposed screen back over endof the remaining insulation and clamp it to a metal surface (seeFigure 6.8 “Wiring of two bay units to be performed by the cu-stomer”). Both the clamp and the metal surface must be electri-cally conducting and corrosion-proof.

Cable insulation

Screen pushedback over endof insulation

Cable clamp

Cores

Figure 6.9 Cable screen termination

It is important that the screen be pushed back over the end ofthe insulation as otherwise it frays with time and the quality ofthe ground connection diminishes. The risk of the screen andcores being pinched is also reduced.

Screens in the case of open frames are also secured by a clampto the mounting plate close to the device as shown in Figure 6.10.


6-13

Station ground

Bear mountingplate with bay unit

Cable screenterminations

Screenedcables

Equipmentframe

Figure 6.10 Cable screen terminations in open equipmentframes (rear view for semi-flush mounting, frontview for surface mounting)

The unscreened ends of the cores going to the device terminalsmust be kept as short as possible and the groups of cablesshould be run separately as explained in Section 6.5.2.2“Internal wiring”.

6.5.3.3. Additional grounding points along cables

Where cubicles are at different potentials, balancing currentscan flow through the screens of cables that are grounded at bothends which induce interference in the cable cores. Where thedistance between the cubicles is greater than approximately10 m, the induced interference can be strong enough to affectthe equipment.

One solution is to run the cables next to the ground rails of thestation grounding mesh and to ground the cables screens every5 to 10 m.

For this purpose, remove a suitable length of insulation and fit aclamp to ground the exposed screen to a grounded metal sur-face. The clamp and the metal surface must be clean, electri-cally conducting and corrosion-proof.

The type of clamp must be chosen such that it holds the cablefirmly without pinching or crushing the screen of the cores.


6-14

6.5.4. Laying optical fibre cables

Refer to the supplier’s instructions for how to lay optical fibrecables. The requirements the optical fibre cables have to fulfilfrom the point of view of the protection are given in Section 3.“Technical specification”. Optical fibre cables may never besharply bent or pinched. Always observe the minimum permissi-ble bending radius.


7-1

June 2000

7. COMMISSIONING

7.1. Safety instructions....................................................................7-37.1.1. Assumptions and preconditions ...............................................7-37.1.2. Regulations ..............................................................................7-3

7.2. General remarks on commissioning theREB500 protection system.......................................................7-4

7.3. Commissioning procedure........................................................7-4

7.4. Checks prior to switching on ....................................................7-57.4.1. Record the equipment data......................................................7-57.4.2. Visually inspect for transport damage ......................................7-57.4.3. Visually inspect the external wiring and cables ........................7-67.4.4. Check the grounding of cubicles and other units .....................7-67.4.5. Check the auxiliary DC battery supply......................................7-67.4.6. Check the settings....................................................................7-77.4.7. Check the c.t. circuits ...............................................................7-87.4.8. Check the v.t. circuits .............................................................7-10

7.5. Commissioning the protection system....................................7-127.5.1. Communicating with the protection system............................7-127.5.1.1. Connecting the PC .................................................................7-127.5.1.2. Minimum PC requirements.....................................................7-127.5.1.3. Starting the operator program ................................................7-137.5.1.4. Simulation of isolator and circuit-breaker position signals......7-137.5.1.5. Comparison of diagrams ........................................................7-137.5.2. Checking the input c.t’s (analogue inputs) .............................7-147.5.3. Checking the input v.t’s (analogue inputs) .............................7-147.5.4. Checking the binary inputs signals (opto-coupler inputs) .......7-147.5.5. Check auxiliary contacts on the isolators and

circuit-breakers and the “CLOSE” command .........................7-157.5.5.1. Timing sequence....................................................................7-157.5.5.2. Auxiliary contact circuit...........................................................7-187.5.5.3. Checking the isolator auxiliary contacts .................................7-197.5.5.4. Checking the circuit-breaker auxiliary contacts

and the manual “CLOSE” command ......................................7-197.5.6. Checking the binary output signals (alarms) ..........................7-197.5.7. Checking the binary output signals (tripping circuits) .............7-207.5.8. Checking the starting of the breaker failure protection...........7-217.5.9. Checking protection stability...................................................7-22


7-2

7.5.9.1. Checking through-fault stability withthe busbars de-energised ......................................................7-22

7.5.9.2. Checking though-fault stability with load current ....................7-247.5.10. Set the system time................................................................7-257.5.11. Final test and inspection ........................................................7-25

7.6. Remote HMI ...........................................................................7-267.6.1. General notes.........................................................................7-267.6.2. Optical fibre link......................................................................7-267.6.3. Modem link.............................................................................7-277.6.3.1. Connecting the modem ..........................................................7-277.6.3.2. Configuring the modem..........................................................7-287.6.3.3. Establishing a modem link .....................................................7-28


7-3

7. COMMISSIONING


7.1.1. Assumptions and preconditions

It is assumed that the REB500 protection system is already in-stalled and all the input and output signals that have been con-figured are also wired and the optical fibre cables run andtested.

It must also be assumed that the busbars or sections of themare in operation and that circuit-breakers and isolators are in theprocess of being installed or maintained.

The commissioning engineer requires the operating instructionsand the station diagrams prepared by the engineering depart-ment.

The protection system may only be commissioned by corre-spondingly trained commissioning personnel.

7.1.2. Regulations

Danger: The greatest care must be taken when testing a bus-bar protection system on busbars in operation, as the conse-quences of tripping a circuit-breaker by mistake when there isno fault, or not tripping it when there is a fault can be extremelyserious.

Danger: Before testing the operation of circuit-breakers or iso-lators, check that no maintenance is being carried out on thecircuit-breakers or the busbars. Even with the power switchedoff, switching operations with people in the vicinity can causeaccidents and injury.

Caution: Unnecessary switching operations should be avoidedas far as possible, because switchgear has a limited number ofoperations and switching disturbs the normal operation of thestation.


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7.2. General remarks on commissioning the REB500 protectionsystem

The REB500 protection system operates digitally and is equippedwith a continuous self-supervision and diagnostics function (seeSection 1.). All the functions are (protection) algorithms com-puted by the system software.

ABB exhaustively tests the system software before it is released.

The customer’s specific data are also recorded in software formin a database, which is similarly tested by the ABB test depart-ment before being released.

The self-supervision function is so extensive that only few hard-ware components are not covered. These include the binary in-puts (opto-couplers) and outputs and the analogue channels (c.t.and v.t. inputs).

For these reasons, it is superfluous to test the internal func-tions of the protection by secondary injection. Secondary injec-tion is therefore restricted to those components which are notcovered by the self-supervision function, i.e. the:

• binary inputs and outputs

• analogue channels.

7.3. Commissioning procedure

The following procedure has proved the best in practice:

Checks prior to switching on

1 Record the equipment data

2 Visually inspect for transport damage

3 Visually inspect the external wiring and cables

4 Check the grounding of cubicles and other units

5 Check the auxiliary DC battery supply

6 Check the settings

7 Check the c.t. circuits

8 Check the v.t. circuits


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Checks after switching on the protection system

9 Secondary injection tests using the test set

10 Check the binary input signals

11 Check auxiliary contacts on the isolators and circuit-breakersand the “CLOSE” command

12 Check the control signal and alarm circuits

13 Check the tripping circuits

14 Check the stability factor

15 Set the system time

16 Final test and inspection.

Note: Fill in the respective pages of the TEST REPORT in Sec-tion 12.5 “Test Report”!

7.4. Checks prior to switching on

7.4.1. Record the equipment data

For purposes of identification and quality assurance, the follow-ing equipment data shall be recorded:

• Rated voltage of the primary plant

• Busbar configuration (double busbars, 1½ breaker scheme etc.)

• Type of station (outdoor/indoor, gas insulated)

• Cubicle number(s)

• Central unit number

• Bay unit designations

• Bay unit numbers

• Software version

• Designations and revision indices of the diagrams.

7.4.2. Visually inspect for transport damage

Deformed housings, dents and damaged paintwork are an indi-cation of transport damage. Where such indications are ob-


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served, check the proper function of the respective unit espe-cially thoroughly and consult the ABB to assess the best courseof action.

Electrical and optical fibre cables must not be bent or pinched.

Check that all the plug-in boards and modules are properly in-serted and secure.

Check that the consignment is complete.

7.4.3. Visually inspect the external wiring and cables

Check that the gauges of all cables are adequate for the currentto be conducted.

Check that the cable screens are properly grounded.

The c.t. circuits should be connected to shorting and isolatingterminals.

The v.t. circuits should be connected to isolating terminals.

Check the tightness of the connections by exerting moderateforce.

Screened leads must be used for c.t. and v.t. circuits as de-scribed in Section 6 “Erection and Installation”.

7.4.4. Check the grounding of cubicles and other units

Cubicles and equipment must be grounded as described in Sec-tion 6 “Erection and Installation”.

7.4.5. Check the auxiliary DC battery supply

Disconnect the auxiliary supply from the protection equipment(green connector).

Check the grounding of the battery supply. The battery circuitcan be grounded

• at either positive of negative pole

• symmetrically via impedances

• not at all (ungrounded).

Check for ground faults if the battery circuit is symmetricallygrounded via impedances or ungrounded.


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Measure the following voltages:

• positive to negative

• positive to ground

• negative to ground.

For higher availability, the station may be equipped with redun-dant auxiliary supplies. In this case, check the second batterysupply in the same way as the first. The two supplies must notbe connected in parallel at any point.

The battery voltage must be within the permissible range of thepower supply unit(s) in the busbar protection system under alloperating conditions (refer to the technical data of the respectivepower supply unit). Check that the battery leads are connectedwith the correct polarity.

If all these checks are satisfactory, reinsert the green auxiliarysupply connectors.

Possible sources of error and helpful hints:

Make sure that the battery circuits are properly protected andmultiple circuits are not interconnected.

Note: Fill in the respective pages of the TEST REPORT in Sec-tion 12.5. “Test Report”!

Caution: Power supply units may never be inserted or with-drawn with the auxiliary supply connected. Therefore place theswitch on the front of the power supply unit in the off positionand unplug the green connector on the end of the battery cable.

The other modules may only be inserted or withdrawn when theswitch on the front of the power supply unit in the off position orthere is no power supply unit fitted.

7.4.6. Check the settings

The commissioning engineer does not generally have to calcu-late or confirm the calculation of the protection settings. He onlychecks and records


7-8

• whether there appear to be basic or obvious errors

• who calculated the settings.


7.4.7. Check the c.t. circuits

Danger: Never interrupt c.t. circuits during operation. Wheremanipulations in c.t. circuits are necessary, be sure to short-circuit them at the shorting and isolating terminals beforehand.After completing work on the c.t. circuits, make sure that theyare closed, i.e. no longer interrupted, and switch the shortingand isolating terminals back to their normal operation positionagain.

Note: The c.t. circuits are not normally tested by the protectioncommissioning engineer. He only records who checked them.

Check that the c.t’s are connected in strict accordance with thediagram supplied.

Perform the following checks to establish the correctness of thec.t’s and c.t. circuits:

Polarity:

The test circuit is given in Figure 7.1.

There must be a positive deflection on the voltmeter when theswitch is closed.

This provisionally checks the c.t. circuit and confirms the polarityof the c.t.


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Figure 7.1 Circuit for checking c.t. polarity

Ratio and wiring:

The c.t. ratios and wiring are checked by primary injection be-tween the three phases R,S and T and ground (R-0, S-0 and T-0) and phase-to-phase (R-S and R-T). The phase and neutralcurrents flowing in protection input circuits are tested.

Apart from checking the ratios and wiring, the phase-to-phaseinjection also checks that all three phases are connected withthe same polarity.

Figure 7.2 Example of primary phase-to-ground injection

Knee-point voltage:

This requires the connection of a test voltage (HV!) to the c.t.secondary and the measurement of current and voltage. Theprimary winding must not be short-circuited.


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The values recorded indicate whether the c.t. has a protection ormetering core. A protection core has a relatively high knee-pointvoltage (the point at which a 10 % reduction of voltage pro-duces a 50 % reduction of current).


The measurement of the knee-point voltage is very impor-tant, because swapped protection and metering cores are notapparent in normal operation, but only when a power systemfault occurs (false tripping of the busbar protection or failure ofthe breaker failure protection to trip may be a consequence).

Figure 7.3 Example of primary phase-to-ground injection

Grounding:

Every electrically insulated c.t. circuit must be grounded at onepoint (of advantage is a point that is accessible during normaloperation).


7.4.8. Check the v.t. circuits

Note: The v.t. circuits are not normally tested by the protectioncommissioning engineer. He only records who checked them.

Check that the v.t’s are connected in strict accordance with thediagram supplied.

Perform the following checks to establish the correctness of thev.t’s and v.t. circuits:


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Polarity:

This test is generally performed on the secondary windings.

Ratio:

Measure the secondary voltage after switching on.

Grounding:

Every electrically insulated v.t. circuit must be grounded at onepoint (of advantage is a point that is accessible during normaloperation).



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7.5. Commissioning the protection system

Danger: To avoid any possible false tripping due to wiring mis-takes, interrupt all the tripping circuits before switching the pro-tection on for the first time.

The protection system is switched on by placing the switch onthe power supply unit in the “ON” position. Providing all the bayunits (BU’s) are switched on and correctly connected by opticalfibre cables to the central unit (CU), the system is ready for op-eration and standing by after the initialisation procedure (about5 min). The display shows, for example:

Ready Alarm Trip

ABB REB 500 V5.00

V1.50AB 99-11-03

Should this not be the case, follow the procedure given in Sec-tion 9 “Trouble-shooting”.

There should not be any alarms, assuming all the isolators andreturn confirmation signals are properly connected and ener-gised (if not, see Section 7.5.1.4. “Simulation of isolator and cir-cuit-breaker position signals”).

Other operations require the connection of a PC in order to beable to communicate with the protection system.

7.5.1. Communicating with the protection system.

7.5.1.1. Connecting the PC

The PC is connected to the central unit or bay unit by means ofthe optical connecting cable supplied.

7.5.1.2. Minimum PC requirements

The PC operator program runs on an IBM PC or compatiblerunning MS Windows. The minimum PC requirements are:

• PC mit INTEL INTEL Pentium 100 MHz or better

• mouse plus PS/2 interface (bus board) if the PC has only oneserial interface


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• Windows 98 or NT 4.0

• MByte RAM (32 MByte recommended)

• 1 floppy (3½", 1.44 MByte) or CD drive

• 1 serial interface (RS-232C, COM1 or COM2)

• SVGA monitor (800 x 600)

• 1 parallel interface (LPT1) for a printer (recommended).

Note: The REBWIN operator program runs under MicrosoftWindows 98 or NT 4.0 with Service Pack 5.

7.5.1.3. Starting the operator program

See Section 4.4 “Starting the operator program”.

7.5.1.4. Simulation of isolator and circuit-breaker position signals

In order to operate, the REB500 protection system requires sig-nals from the isolators and circuit-breakers indicating their posi-tions. If one or several positions are unknown, the protectionsystem starts incompletely. It is only fully operational and stand-ing by when all the position signals are available.

At the beginning of commissioning, these signals are frequentlyincorrectly wired or the supply for the auxiliary contacts is notswitched on. To enable commissioning of the protection systemto proceed in spite of this, the positions of the isolators and cir-cuit-breakers have to be simulated. This can be achieved eitherusing jumpers at the terminals or by simulating opto-coupler po-sitions in the test mode.

Once this has been done, no alarms with the exception of “Testgenerator active) may be active.

7.5.1.5. Comparison of diagrams

Now compare the REB500 diagram with the station diagram (bi-nary and analogue inputs and binary outputs).


Check that the actual c.t. locations in the single-line diagram inthe REB500 database agree with their locations in the station.


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7.5.2. Checking the input c.t’s (analogue inputs)

Using a test set, SVERKER or MODURES Type XS92b, inject acurrent into each of the c.t. inputs.

The c.t’s can be checked in one of the following ways:

• Reading the injected currents on the local control unit. (Note:The readings are referred to the primary values.)

• Reading the injected currents via the REBWIN operator pro-gram by selecting “Analogue input measurements” in the“View” menu.

• Reading the injected currents via the REBWIN operator pro-gram by selecting “Protection zone measurements” in the“View” menu.

• Increasing the currents until the protection function (e.g. bus-bar or end fault protection function) picks up.

The last alternative, increasing the current until the protectionfunction picks up is the one normally chosen, but this is not im-perative.


7.5.3. Checking the input v.t’s (analogue inputs)

Using a test set, SVERKER or MODURES Type XS92b, inject avoltage into each of the c.t. inputs.

Read the voltage applied on the local control unit. (Note: Thereadings are referred to the primary phase-to-ground voltage.)


7.5.4. Checking the binary inputs signals (opto-coupler inputs)

Check the proper function of every binary opto-coupler input byexciting the signal source.

The binary inputs can be checked in one of the following ways:

• Reading the statuses on the local control unit.


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• Reading the statuses via the REBWIN operator program byselecting “Binary input/output status” in the “View” menu.

• Checking the events generated in the event list.

The event list enables the correct assignment of the signals aswell as their operation to be checked.


7.5.5. Check auxiliary contacts on the isolators and circuit-breakers and the “CLOSE” command

7.5.5.1. Timing sequence

To be able to operate discriminatively, the protection has toknow the actual configuration of the busbars. For this purpose,auxiliary contacts on the isolators and circuit-breakers mustbe connected to the binary inputs of the respective bay units.

Thus every isolator and circuit-breaker has to be equipped withpotentially-free normally open and normally closed contacts, theN/O contact signalling that the corresponding switching device isclosed and the N/C contact that it is open.

During the closing operation of an isolator, the N/O contact mustalready signal its closed status before the main contacts reachtheir breakdown voltage.

Conversely, during the opening operation, the N/O contact(“CLOSED” signal) should not open before the main contactshave exceeded their breakdown voltage and it is impossible foran arc to ignite. If this condition cannot be fulfilled, i.e. the N/Ocontact signals that the isolator is open before it has reached itsbreakdown voltage, the N/C contact must not close before themain contact exceeds its breakdown voltage.


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Figure 7.4 Isolator timing sequence

The protection system supervises that only one signal is beinggenerated (i.e. either “CLOSED” or “OPEN”), otherwise an iso-lator alarm is given after a delay. The alarm can be configured toblock the protection if necessary. If the auxiliary contacts do notfulfil the above conditions, the logic “Not OPEN = CLOSED” canbe used. This, however, is only permissible if the isolator auxil-iary supply is supervised by connecting it to one of the signal in-puts.


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Figure 7.5 “Not OPEN = CLOSED” logic

Inverting the logic enables local events to be generated while abay unit is starting that signal a change of input status that didnot take place. This does not impair correct operation.


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7.5.5.2. Auxiliary contact circuit

The N/C auxiliary contacts of phases L1, L2 and L3 must beconnected in series and the N/O contacts in parallel.

Figure 7.6 Isolator and circuit-breaker positions and manualCLOSE signals

The isolator and circuit-breaker position signals are evaluated asfollows:

N/O aux. contact:isolator/circuit-breaker “CLOSED”

N/C aux. contact:isolator/circuit-breaker “OPEN”

Isolator/circuit-breakerposition

Open Open Last position recorded.+ alarm after delay+ switching forbidden signal

Open Closed OPEN

Closed Open CLOSED

Closed Closed CLOSED+ alarm after delay+ switching forbidden signal


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7.5.5.3. Checking the isolator auxiliary contacts

Check the timing sequence of the isolator auxiliary contacts byinspecting the construction of the isolator or assessing it fromthe respective data sheet.

Verify the operation of the “CLOSED” and “OPEN” contacts ac-cording to the circuit diagram and by physically opening andclosing the isolator.


7.5.5.4. Checking the circuit-breaker auxiliary contacts and themanual “CLOSE” command

Check and verify the operation of the circuit-breaker auxiliarycontacts in the same way as for the isolators.

Check for every configured circuit-breaker that its “CLOSED”signal (command) is detected by the protection, i.e. “CLOSE”commands from local and remote devices, from the stationautomation system (SAS) or from the auto-reclosure equipment.


7.5.6. Checking the binary output signals (alarms)

The contact load and rupture capacity given in Section 3 “Tech-nical specification” must not be exceeded.

Set the operator program to the test mode by selecting “Testmode” from the “Testing” menu. This requires the input of thecorrect password.

Note: To enable a start to be made, the password is set to“Test” when the program is supplied.

Click on the “Unblock all relays” button in the test mode dia-logue.


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In the test mode, select “Binary input/output status” in the “View”menu to view the outputs of a binary module. The status of anoutput can be changed by double-clicking on the correspondingfield, which then changes to yellow.

Figure 7.7 REBWIN dialogue for viewing output statuses afterselecting “Binary input/output status” in the “View”menu

Check the external alarm by activating the output relay.

Caution: All external relay coils must be fitted with freewheeldiodes or voltage-dependent resistors (VDR’s).


7.5.7. Checking the binary output signals (tripping circuits)

The contact load and rupture capacity given in Section 3 “Tech-nical specification” must not be exceeded.

Circuit-breakers are frequently equipped with two completely in-dependent tripping circuits. In such cases, check that both areindependently controlled by REB500.

Caution: Test operations of circuit-breakers and isolators re-quire the permission of the user and all the prescribed safetyprecautions must be observed.

The tripping circuits are tested in the same way as the alarm cir-cuits by setting them appropriately in the test mode.


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Figure 7.8 REBWIN dialogue for viewing output statuses afterselecting “Binary input/output status” in the “View”menu

Check that the correct circuit-breaker trips and by the correcttripping coil.


7.5.8. Checking the starting of the breaker failure protection

The breaker failure protection is started by various other protec-tion functions and therefore its connections to each of themhave to be checked (same procedure as in Section 7.5.4“Checking the binary inputs signals (opto-coupler inputs)”).

Basically, every protection function that can trip the circuit-breaker should also start the breaker failure protection. Theseare typically:

• Busbar protection (When busbar and breaker failure protec-tion functions are performed by the REB500, the connectionbetween the two is part of the software.)

• Line protection (distance or longitudinal differential)

• Remote trip from the other end of a line (direct transfer trip-ping)

• Transformer protection (differential, Buchholz or overtem-perature)

• Overcurrent protection.

Starting has to be single-phase where single-phase reclosure isbeing applied, otherwise three-phase starting is permissible.


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7.5.9. Checking protection stability

Proper operation of the protection system can only be assured ifthe stability check includes all the feeders.

Wherever possible the stability should be checked before thebusbar is energised, because the risk of a busbar fault is espe-cially high when it is being energised for the first time (flash-overs, grounding isolators still closed etc.).

7.5.9.1. Checking through-fault stability with the busbars de-energised

Inject a current from a primary injection test set (25 % of the c.t.rated current is recommended) into two feeders (a referencefeeder and one other feeder, see Figure 7.9). Any feeder can beused as reference. Compare each of the other feeders and bus-tie breaker with the reference feeder.

If a bus-tie breaker is only equipped with one set of c.t’s, notethat the they are used by two busbar sections.

In the case of a bus-tie breaker equipped with two sets of c.t’s(Figure 7.10), make sure that the set of c.t’s assigned to thebusbar section under test is checked. The simplest way of en-suring this is to short-circuit the c.t’s belonging to the section notunder test directly at the c.t’s or as close as possible to them.

The feeder currents and the differential current can be read us-ing the operator program on the PC.

The comparison with the reference feeder must be conductedfor phase and neutral currents for protection schemes thatevaluate the neutral current.


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Reference feeder

Primaryinjectiontest set

I

II

Figure 7.9 Test set-up for checking protection through-faultstability by primary injection (feeders)

Reference feeder

Primaryinjectiontest set

Short-circuit c.t’s

I

II

Figure 7.10 Test set-up for checking protection through-faultstability by primary injection on busbar I (bus-tiebreaker with two sets of c.t’s)


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7.5.9.2. Checking though-fault stability with load current

Where protection stability cannot be tested before the busbar isenergised or in the case of an extension to an existing system, ithas to be tested using load current.

Caution: For this test, either tripping by the protection has to beblocked or the tripping circuits have to be interrupted before thecurrents are applied to the protection.

In order to carry out the test, all the amplitudes and directions ofthe primary currents must be known. Perform one of the following:

Alternative a) Short-circuit the c.t’s and isolate them from theprotection.

Alternative b) Use the test mode to simulate that all the isola-tors are open (this is the simpler method).

In the case of a), connect the infeeds one by one, or in the caseof b), simulate the closure of the isolators one by one. Which-ever method is chosen, check that the differential current in-creases as each infeed is connected (either on a PC using theoperator program or on the local control unit of the central unit).Repeat this procedure with the loads and the differential currentmust reduce as each feeder is connected.

In the case of systems which evaluate the neutral current, the dif-ferential current of the neutral measurement must be checked aswell. A neutral current has to be simulated in a symmetrical powersystem in order to perform the stability test (see Figure 7.11).

Figure 7.11 Testing the through-fault stability of the neutral circuit


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Caution: Take great care not to open-circuit a c.t. secondary bymistake.

Any other protection devices in the same c.t. secondary circuitmust not be influenced in any way (e.g. transformer differentialprotection or earth fault relays).


7.5.10. Setting the system time

Set the date and local time by selecting “Set system time” in the“Tools” menu.

7.5.11. Final test and inspection

Print the report with all the settings and the configuration by se-lecting “Reports” in the “Tools” menu and checking the “Print allreports” checkbox in the dialogue that opens (see Section 4.5.36“Tools/Reports”).

Check all the settings and the configured features such as as-signment of modules, auxiliary supply values and the assign-ment of signals to each opto-coupler input and relay output onceagain in the report.

Visually check that all the temporary changes have been re-moved and the system restored to its operational state. Payspecial attention to:

• interrupted tripping circuits

• interrupted alarms

• interrupted input signals

• short-circuited c.t’s

• interrupted v.t’s.

Make sure that the report has been completely filled in.


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7.6. Remote HMI

In addition to the optical interface on the front of the local controlunit, the REB 500 central unit or a bay unit can also be con-nected to the PC via a serial interface at the rear. This interfaceis intended for communication over some distance by means ofan optical fibre cable or a modem.

7.6.1. General notes

Modem and optical fibre cable are connected to the 25 pin Sub-D connector marked SERIAL PORT 2 on the CMP. The inter-face is permanently configured for 9600 Baud, 8 bit, no parityand 1 stop bit.

For safety reasons, only one of the two REBWIN interfaces maybe in use at any one time, i.e. either the one on the front of thelocal control unit or the remote connection to the CMP at therear. When REB 500 is started, both interfaces are active. Assoon as REBWIN is started on the PC connected to one ofthem, the other interface is disabled and remains so until theconnection with REBWIN is interrupted (i.e. until REBWIN isshut down on the PC). Both interfaces are then enabled andstanding by again until REBWIN establishes communication withone of them.

7.6.2. Optical fibre link

Two electrical-to-optical converters and two optical cables areneeded before REBWIN can communicate with REB 500. De-pending on the distance, either optical fibre cables with plastic orglass cores are used.

Optical fibre cables with plastic cores are permissible for dis-tances up to 30 m. Complete cable kits (2 converters and ca-bles) can be ordered as accessories under the following num-bers:

Type Order No. Part No.

YX216a-1 (4 m) 7433 1640 – AA HESG448522 R1

YX216a-1 (10 m) 7433 1640 – BA HESG448522 R2

YX216a-1 (30 m) 7433 1640 – CA HESG448522 R3


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Optical fibre cables with 62.5/125 mm glass cores and appropri-ate converters such as Hirschmann OZDV 2451 G (HirschmannOrder No. 943 299-021) are recommended for distances greaterthan 30 m.

The converter at the REB500 end should be configured as DCEand the one at the PC end (with 25 to 9 pin adapter) as DTE.

7.6.3. Modem link

Modems are needed at both ends to enable a PC runningREBWIN to communicate with REB 500 via a telephone line.ABB does not supply modems as accessories and thereforestandard commercially available modems must be procured. Werecommend studying the modem manual carefully to avoidproblems during installation and operation.

We recommend a modem with automatic call-back for use withthe REB500. A modem of this kind requires the caller to enter apassword. The connection is then interrupted and providing thepassword was correct, the modem calls back the number for theparticular password. This procedure ensures that only author-ised personnel can communicate with the protection device. Thepasswords and associated telephone numbers are entered inthe modem connected to the REB500. Consult the instructionsfor the modem for the corresponding AT commands. In mostcases, configuration software is supplied with the modem whichgreatly simplifies setting the modem.

Once all the settings have been made, the changes have to besaved using the corresponding AT command given in the in-structions for the modem.

7.6.3.1. Connecting the modem

The modem is connected to SERIAL PORT 2 on CMP inREB 500 by a 25 pin cable.

The cable pins 2 (TX) and 3 (RX) need to be crossed.

Caution: To maintain EMC, the modem may only be connectedvia an electrically insulated RS232 input device.


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7.6.3.2. Configuring the modem

A standard terminal program must be installed on the PC (e.g.Microsoft “Terminal” supplied with Windows) to configure themodem. The terminal program itself must be configured to usethe COM port to which the modem is connected.

Both modems:First check the correct operation of the modem by entering AT<Return>. The modem must respond with OK (or 0).

Set the communication parameters to 9600 Baud, 8 bit, noparity and 1 stop bit.

Disable both software and hardware handshakes. Consult themodem manual for the corresponding command.

REB 500 modem:Set the modem to “Automatic answer”. The command formost modems is AT S0=3, 3 being the number of rings beforethe modem answers.

PC modem:Disable the DTR (data transmission ready) signal in the mo-dem at the PC end. This is necessary to facilitate changingfrom terminal operation to REBWIN operation without inter-rupting the communication channel. Consult the modemmanual for the corresponding command.

7.6.3.3. Establishing a modem link

1 Start the “Terminal” program on the PC.

2 Dial the telephone number for the protective device, respec-tively the modem connection.

3 Wait until the two modems establish the connection. If thecall-back mode was configured, enter your password andwait for the call-back and for the two modems to establishconnection.

4 Close the “Terminal” program and start REBWIN.

5 Close REBWIN in the normal way to terminate communica-tion and shut the link down. The modem can then beswitched off or the channel shut down using the “Terminal”program.


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June 00

8. Operation and maintenance

8.1. Operation .................................................................................8-38.1.1. Safety instructions....................................................................8-38.1.2. General ....................................................................................8-38.1.3. Viewing data on the local control unit (HMI).............................8-38.1.4. Starting the protection system..................................................8-68.1.5. Normal operation .....................................................................8-68.1.5.1. Measurements .........................................................................8-78.1.5.2. Differential current....................................................................8-78.1.5.3. Inputs .......................................................................................8-78.1.5.4. Outputs ....................................................................................8-78.1.5.5. Global settings .........................................................................8-78.1.5.6. Settings ....................................................................................8-78.1.5.7. System response .....................................................................8-78.1.5.8. Busbar protection.....................................................................8-78.1.5.9. Operating characteristic ...........................................................8-88.1.6. Failure of the protection ...........................................................8-88.1.6.1. Unexpected restart...................................................................8-98.1.6.2. Differential current alarm..........................................................8-98.1.6.3. Isolator alarm .........................................................................8-108.1.7. Protection blocking functions .................................................8-118.1.8. Protection tripping ..................................................................8-128.1.8.1. Resetting latched signals and relays......................................8-128.1.8.2. Tripping ..................................................................................8-138.1.8.3. Trip list ...................................................................................8-148.1.8.4. Reading disturbance recorder data........................................8-148.1.9. Special operating modes........................................................8-148.1.9.1. Inspection and maintenance ..................................................8-148.1.9.2. Transfer tripping.....................................................................8-158.1.9.3. Isolator auxiliary contact logic “Not OPEN=CLOSED” ...........8-168.1.9.4. Activating and deactivating configured feeders......................8-16

8.2. Maintenance ..........................................................................8-19

8.3. System additions, spare units and checks .............................8-208.3.1. Activating a previously configured feeder...............................8-208.3.2. Replacing a bay unit...............................................................8-238.3.3. Example: Maintenance check on a feeder circuit-breaker .....8-248.3.3.1. Step 1.....................................................................................8-268.3.3.2. Step 2.....................................................................................8-288.3.3.3. Step 3.....................................................................................8-29


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8.3.3.4. Step 4.....................................................................................8-318.3.3.5. Step 5.....................................................................................8-328.3.3.6. Step 6.....................................................................................8-338.3.3.7. Step 7.....................................................................................8-338.3.4. Example: Maintenance check on a bus-tie breaker ...............8-348.3.4.1. Step 1.....................................................................................8-348.3.4.2. Step 2.....................................................................................8-358.3.4.3. Step 3.....................................................................................8-358.3.4.4. Step 4.....................................................................................8-368.3.4.5. Step 5.....................................................................................8-368.3.4.6. Step 6.....................................................................................8-36


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8. Operation and maintenance

8.1. Operation

8.1.1. Safety instructions

Caution: Only properly trained and authorised personnel shouldbe in possession of the REBWIN password.

Caution: Checks and maintenance on the REB500 system mayonly be carried out by properly trained personnel.

8.1.2. General

Operation in the case of the REB500 busbar protection systemis confined to supervising the proper function of the system andassessing the system data.

There are different procedures for reading operating, disturban-ce and tripping data:

• on the local control unit

• on a PC running the REBWIN operator program

• via remote control

• by the station automation system (SCS).

8.1.3. Viewing data on the local control unit (HMI)

The local control unit permits control functions to be performedlocally on the equipment.

The different coloured LED’s signal the various operating sta-tuses of the protection system and supplementary information isdisplayed on the LCD.

The following data can be viewed on the central control unit:

• current and voltage measurements

• statuses of inputs and outputs

• alarms (generated by the respective bay unit)

• system (or respective bay unit) settings

• settings of all the specific bay unit protection functions.


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yellow redgreen LED’s:

Optical PC interface

Figure 8.1 Local control unit (HMI)

Pushbuttons

Button EPress button E to go to the next menu down.

Button CPress button C to return to the main menu. If Reset latching isthe current menu, pressing this button resets any relays thatare latched.

Arrow buttonsThe buttons marked “↑” and “↓” are for scrolling through dis-plays of information needing more than four lines.The buttons marked “←” and “→” are for moving through themenus item by item.


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Menu structure of the central unitAlarmsTripsReset latchingCentral unit

Meas. var.Bus zones



... (other bus zones as configured)Inputs

Slot 19 (where fitted)Slot 20 (where fitted)

OutputsSlot 19 (where fitted)Slot 20 (where fitted)

Global valuesSettings

System responseBusbar protection

PhasesNeutral

Bay unitsBay unit 1

Meas. var.CurrentsVoltagesInputs


OutputsSlot 5Slot 4 (where configured)

Circuit-breakersBreaker designation... (where configured)

SettingsBBPBFP (where configured)OCDT (where configured)EFP (where configured)PDF (where configured)

Bay unit 2See bay unit 1

... (other bay units as configured)


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Menu structure of the bay unitAlarmsTripsReset latchingSettings

Global valuesSystem responseBBP

Phases Neutral current Overcurrent enable

BFP (where configured)OCDT (where configured)EFP (where configured)PDF (where configured)

Measured variablesCurrentsVoltagesInputs

Slot 1Outputs

Slot 1Circuit-breakers

Breaker designation... (where configured)

8.1.4. Starting the protection system

After switching on the auxiliary supply the following is displayedon the central unit and bay units:

HMI text LED’s Event

- The three LED’sflash

-

Table 8-1 System initialisation

It takes about 6 minutes to initialise the system.

8.1.5. Normal operation

Central unit and bay units


ABB REB500 V5.0V1.00A 99-12-05

Green lit -

Table 8-2 Normal operation

Using the arrow buttons to navigate through the menu structure,additional information can be view on the LCD.


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8.1.5.1. Measurements

The measurements that can be viewed on the LCD are the diffe-rential currents of the various busbar zones and the statuses ofthe binary inputs and outputs on the BIO modules in the centralunit.

8.1.5.2. Differential current

The differential currents of the various busbar zones are dis-played on the LCD of the central unit. Where the configuration ofthe busbars is such that several busbar zones are connected toform a single zone, the identical differential current is displayedfor the individual zones.

8.1.5.3. Inputs

The statuses of the opto-coupler inputs on each of the binary in-put/output modules in the central unit are displayed as a bit pat-tern, a logical “1” indicating an active input (i.e. the input voltageis higher than the pick-up voltage) and a logical “0” an inactiveinput. In the row of 12 binary digits (“1” or “0”), opto-coupler 1 ison the left and opto-coupler 12 on the right.

8.1.5.4. Outputs

The statuses of the outputs on each of the binary input/outputmodules in the central unit are displayed as a bit pattern, a logi-cal “1” indicating a set output. Output 1 is on the left of the bitpattern and output 9 on the right.

8.1.5.5. Global settings

This menu item displays the set power system frequency.

8.1.5.6. Settings

This menu item displays those settings which determine the re-sponse of the entire system and the busbar protection.

8.1.5.7. System response

How the system responds to a differential current or isolatoralarm (i.e. what is blocked and what is not), the isolator opera-ting time and the width of the transfer tripping impulse are dis-played.

8.1.5.8. Busbar protection

The settings determining the response of the busbar protectionto phase faults and, where configured, to ground faults are dis-played.


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8.1.5.9. Operating characteristic

The settings determining the operating characteristic of the re-strained current amplitude comparison algorithm are displayed:

• IKmin min. fault current

• k k factor

• Differential current alarm differential current supervision

• Time delay delay of the differential currentalarm

8.1.6. Failure of the protection

This Section lists the signals that appear when the protectionhas failed or is blocked, the likely causes and suggestions forcorrective action.

Alarms and signals are generated for the following events:



General alarm Green lit, yellowflashes untilbutton on thelocal control unitpressed

CU: “41805_Alarm”

BU: No event

Table 8.3 Protection failure

Possible causes:

• Auxiliary supply failure

• Failure of a board in the central unit

• Failure of the communication with a bay unit

• Failure of a bay unit

• Failure of a bay unit application

• Error while updating the protection system data

• Failure of the internal communication in the central unit

• Operation of supervision devices for fans or any external po-wer supplies (“31815_Ext. superv. in service_1” at logical “0”).


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8.1.6.1. Unexpected restart

Central unit



CU: “41810_In service” resets

Table 8-4 Central unit restarts

Possible causes:The central unit is no longer in the standby status and restarts.

Corrective action:Discuss event list with the operations manager without delay.

Bay units



BU: “21805_In service” resets

Table 8-5 Bay unit restarts

Possible causes:A bay unit is no longer in the standby status and restarts.

Corrective action:Discuss event list with the operations manager without delay.

8.1.6.2. Differential current alarm

Central unit


Diff. cur. alarm Green lit, yellowflashes untilbutton on thelocal control unitpressed

CU: “41815_Diff. current alarm”active

Table 8-6 Differential current alarm on the central unit


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Possible causes:Fault in one or several current circuits (between c.t’s and bayunits). The fault can be located by checking the current measu-rements by each of the bay units.

Corrective action:Block the protection.

Compare all the feeder currents with the values displayed in thecontrol room.

If differential current is flowing in two busbar zones, check theisolator image.

Check the directional comparison measurement:Short circuit all the c.t’s at the inputs of the bay units of feederssupplying energy to the busbars in the phases and busbar zonesconcerned. The differential current must increase with each in-feed that is short-circuited. Should this not be the case, checkthe c.t. circuit of the feeder that does not produce an increase(all screws tight and jumpers correct?). If the fault cannot be lo-cated, continue with the c.t’s of feeders conducting energy awayfrom the busbars. In this case, the current must reduce witheach feeder short-circuited. Should this not be the case, checkthe c.t. circuit of the feeder that does not produce a decrease.

8.1.6.3. Isolator alarm



Isol. alarmFeeder nameIsol. alarm

Green lit, yellowflashes untilbutton on thelocal control unitpressed

CU: “41505_Isolator alarm” activeCU: “41830_Switch inhibit” activeBU: No event

Table 8-7 Isolator alarm

Possible causes:Either the isolator auxiliary supply for a feeder has failed or the“CLOSED” and “OPEN” signals are both active together.

Corrective action:Measure the isolator image signal voltages at the opto-couplerinputs and if both are present, check the circuits back to the au-xiliary contacts (no voltage, open-circuit lead or incorrect opera-tion of the isolator auxiliary contacts).


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8.1.7. Protection blocking functions



<Subsystem>blocked(Subsystem =BBP, BFP, EFP,OCDT, PDF)


CU: “41405_All blocked” activeBU: “21405_All blocked” active

Contacts blocked Green lit, yellowflashes untilbutton on thelocal control unitpressed

CU: “41410_Output relays blocked”active

BU: “21410_Output relays blocked”active

BBP blockedFeederBBP blocked


CU: “42405_BBP blocked” activeBU: “22405_BBP blocked” active

BFP blockedFeederBFP blocked


CU: “43405_BFP blocked” activeBU: “23405_BFP blocked” active

EFP blockedFeederEFP blocked


CU: “45405_EFP blocked” activeBU: “25405_EFP blocked” active

OCDT blockedFeederOCDT blocked


CU: “45405_OCDT blocked” activeBU: “25405_OCDT blocked” active

PDF blockedFeederPDF blocked


CU: “47405_PDF blocked” activeBU: “27405_PDF blocked” active

Table 8-8 Blocking protection functions


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Possible causes:The blocking of a protection function is due to either an activeopto-coupler input or an internal alarm, e.g. differential currentalarm.

Corrective action:Corrective action is only necessary if blocking is unintentional. Ifthis is the case, check whether a voltage is being applied to aninput which indicates a likely fault in the external circuit. If thefault appears to be caused by an internal alarm, check whetherthere is a corresponding display and correct the cause of thealarm (see instructions for the corresponding alarm).

8.1.8. Protection tripping

A trip is indicated by the red LED on the front of the central unitand the bay unit concerned. The text on the display disappearsas soon as any button on the respective unit is pressed. The textis also added to a list in the central unit and in the bay unit con-cerned.

8.1.8.1. Resetting latched signals and relays


Reset latchingC: ResetE: Quit

- -

Table 8-9 Resetting latched signals and relays

Latched signals and relays can be reset by pressing button “C”or the corresponding reset button.

To prevent an active trip from being reset by mistake, the button“C” has to be pressed to reset a latched trip signal, which is notwhat one would expect from the assigned functions of the but-tons on the local control unit.


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8.1.8.2. Tripping

Central unit


Date TimeTRIPFeeder nameBus zone *

Green lit, red lit CU: “42305_BBP trip” activeCU: “42310_BBP trip L0” activeCU: “42315_BBP trip L1” activeCU: “42320_BBP trip L2” activeCU: “42325_BBP trip L3” active

Date TimeBFP trip t 1/2Feeder name

Green lit, red lit CU: “43305_BFP trip t1” activeCU: “43310_BFP trip t2” active

Date TimeEFP tripFeeder name

Green lit, red lit CU: “44305_EFP trip” active

Date TimeOCDT tripFeeder name

Green lit, red lit CU: “45305_OCDT trip” active

Date TimePDF tripFeeder name

Green lit, red lit CU: “47305_PDF trip” active

Table 8-10 Central unit trips


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Bay units


Date TimeBBP TRIP

Green lit, red lit BU: “21110_TRIP” activeBU: “21115_REMOTE_TRIP” activeBU: “21305_BBP Trip” active

Date TimeBFP trip t 1/2

Green lit, red lit BU: “23105_BFP TRIP” activeBU: “23110_BFP_REMOTE_TRIP”

activeBU: “23305_BFP trip t1” activeBU: “23310_BFP trip t2” activeBU: “23315_BFP TRIP L1” activeBU: “23320_BFP TRIP L2” activeBU: “23325_BFP TRIP L3” activeBU: “23335_BFP Trip by BFP” acti-

ve

Date TimeEFP trip

Green lit, red lit BU: “24105_EFP REMOTE TRIP”active

BU: “24305_EFP trip” active

Date TimeOCDT trip

Green lit, red lit BU: “25105_OCDT TRIP” activeBU: “25305_OCDT trip” active

Date TimePDF trip

Green lit, red lit BU: “27105_PDF TRIP” activeBU: “27305_PDF trip” active

Table 8-11 Bay unit trips

8.1.8.3. Trip list

The last 20 trips are recorded in a non-volatile memory. Thedetails of a particular trip can be viewed by selecting it in the list.The last trip is at the top of the list.

8.1.8.4. Reading disturbance recorder data

Refer to Section 4.5.13. “View/Disturbance recorder”.

8.1.9. Special operating modes

8.1.9.1. Inspection and maintenance

The inspection status is signalled when an inspection/main-tenance input is active (see Section 3.4.1.5. “Inspection andmaintenance”).


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Caution: The information on the positions of the isolators is lostif the bay unit is switched off or reset and the actual positionsare detected when it starts again.This causes an isolator alarm which disappears as soon as themaintenance signal resets. An active isolator alarm in themaintenance mode thus means that the isolator positions beingsignalled may have changed.

Central unit


Insp./MaintenanceFeeder name


CU: “41825_Inspection/main-tenance” active

Table 8-12 Inspection/maintenance on central unit

Bay units


InspectionInspection number


BU: “21815_Inspection/main-tenance” active

Maintenance Green lit, yellowflashes untilbutton on thelocal control unitpressed

BU: “21815_Inspection/main-tenance” active

Table 8-13 Inspection/maintenance on bay units

8.1.9.2. Transfer tripping

A transfer trip is signalled when a transfer trip input is active (seeSection 11.1.3.2.).


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Central unit


Trip transferred Green lit, yellowflashes untilbutton on thelocal control unitpressed

Depends on configuration

Table 8-14 Transfer trip

8.1.9.3. Isolator auxiliary contact logic “Not OPEN=CLOSED”

A failure of the isolator image auxiliary supply is signalled whenthe isolator auxiliary contact logic “Not OPEN=CLOSED” is acti-ve:

Central unit


Isol. alarmFeeder nameIsol. alarm


CU: “41505_Isolator alarm” activeCU: “41830_Switch inhibit” activeCU: “41820_Loss of supply voltage”

activeBU: “21810_Loss of supply voltage”

active

Table 8-15 Isolator alarm for “Not OPEN=CLOSED” logic

8.1.9.4. Activating and deactivating configured feeders

Standard procedureThe procedure for activating and deactivating configured feedersis as follows:

1 Start REBWIN.

2 Block REB500 by setting the input “Block all” on the centralunit.

3 Any bay unit that needs to be deactivated must be switchedoff.

4 Select “Installation mode” in the REBWIN “Testing” menuand then click on “Delete database in the protection system”to delete the existing REB500 database. REBWIN then clo-ses automatically.


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5 Start REBWIN again when “Load database” appears on thelocal control unit.

6 Download the database with the changed data by selecting“Download to protection system” in the REBWIN “File” menu.REB500 then restarts automatically.

Figure 8.2 “ABB references” tab in the “Activate/deactivate”dialogue of the “Configuration” menu

Caution: Activating and deactivating single items of plant suchas a single isolator can have an unforeseeable effect on the re-sponse of the protection system. When an item of plant is de-activated, the tripping and intertripping logics change and the-refore it should only be done following consultation with ABB.

ABB accepts no responsibility for errors when using thisfunction.


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Figure 8.3 “Modules in the central unit” tab in the “Activa-te/deactivate” dialogue of the “Configuration” menu

Figure 8.4 “System objects” tab in the “Activate/deactivate”dialogue of the “Configuration” menu


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Special procedure (for CPU 04)It occurs occasionally that the database is not completely dele-ted and REB500 cannot be restarted. In this case, the followingprocedure has to be followed:

1 Close REBWIN.

2 Switch off all the bay units.

3 Connect the PC to the central unit and start REBTERM.

4 Switch off the central unit and switch it on again while pres-sing the space bar <SPACE> until the monitor program re-turns

SiMon CU #5 >

5 Delete the database by entering:

SiMon CU #5 > ee 24:30 (CPU04)

6 Switch the central unit off and back on again.

7 Wait until

Load database

appears on the local control unit.

8 Start REBWIN:

9 Download the changed database to REB500 by selecting“Download to protection system in the “File” menu.

10 Switch on all the activated bay units.

8.2. Maintenance

The REB500 protection system operates electronically and doesnot contain any mechanical parts that are subject to wear andtear. The system does not therefore require any maintenance.

Depending on the ambient conditions, we recommend removingthe dust (e.g. with a vacuum cleaner) and wiping the front of theLCD with a damp cloth (perhaps with a little washing up liquid)from time to time. Do not use petrol or cleaning agents contai-ning alcohol.

Software routines continuously supervise the operation of theREB500 busbar protection, which therefore does not require pe-riodic inspection. Nevertheless, since the protection equipmentis only part of the overall protection system, we recommend pe-riodically checking all the parts that are not automatically super-vised. The test procedure illustrated by the examples in Sections


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8.3.3. and 8.3.4. should be performed on all circuit-breakers atintervals of approximately two years.

8.3. System additions, spare units and checks

8.3.1. Activating a previously configured feeder

Where REB500 was configured for the final state of a stationand one of the previously configured feeders is installed andequipped with a bay unit, it has to be activated in the system tobe included in the protection. The procedure in this case is:

1 Start REBWIN.

2 Block REB500 by setting the input “Block all” on the centralunit.

3 Select “Installation mode” in the REBWIN “Testing” menuand then click on “Delete database in the protection system”to delete the existing REB500 database. REBWIN then clo-ses automatically.

4 Start REBWIN again when “Load database” appears on thelocal control unit.

5 Download the database with the changed data by selecting“Download to protection system” in the REBWIN “File” menu.REB500 then restarts automatically.



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Figure 8.5 “ABB references” tab in the “Activate/deactivate”dialogue of the “Configuration” menu

Caution: Activating and deactivating single items of plant suchas a single isolator can have an unforeseeable effect on the re-sponse of the protection system. When an item of plant is de-activated, the tripping and intertripping logics change and the-refore it should only be done following consultation with ABB.

ABB accepts no responsibility for errors when using thisfunction.


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Figure 8.6 “Modules in the central unit” tab in the “Activa-te/deactivate” dialogue of the “Configuration” menu

Figure 8.7 “System objects” tab in the “Activate/deactivate”dialogue of the “Configuration” menu


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Special procedure (for CPU 04)

It occurs occasionally that the database is not completely dele-ted and REB500 cannot be restarted. In this case, the followingprocedure has to be followed:

1 Close REBWIN.

2 Switch off all the bay units.

3 Connect the PC to the central unit and start REBTERM.

4 Switch off the central unit and switch it on again while pres-sing the space bar <SPACE> until the monitor program re-turns

SiMon CU #5 >

5 Delete the database by entering:

SiMon CU #5 > ee 24:30 (CPU04)

6 Switch the central unit off and back on again.

7 Wait until

Load database

appears on the local control unit.

8 Start REBWIN:

9 Download the changed database to REB500 by selecting“Download to protection system in the “File” menu.


8.3.2. Replacing a bay unit

When connecting a bay unit to a central unit for the first time, forexample, when replacing a defective module, it is necessary toconfigure the communications parameters, the node ID and thedevice ID as they were on the old unit.

Caution: Incorrect or incorrectly executed settings will preventthe bay unit from starting and can disable the entire system.

Refer to the report “Bus section and device allocation” (see Sec-tion 4.5.36. “Tools/Report”) for the values that have to be set,the bus section being the node ID.


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The setting procedure is as follows:

1 Switch on the bay unit.

When this display appears onthe local control unit, press the“E” button.

SiMon PPC Vx.xy

Press E forSet-Up ....

2 The current setting appears onthe local control unit.

Use the arrow buttons “←” and“→” to change a value and movefrom one value to the next using“↑” and “↓”.

MVB parameters node ID = nnn device ID = dddE=Save C=Cancel

3 The new values are displayedand have to be confirmed bypressing the “E” button.

Saving MVB para. (N:nnn D:ddd)E=ConfirmC=Quit

Once the values have been confirmed, the bay unit restarts au-tomatically with the new communication settings.

8.3.3. Example: Maintenance check on a feeder circuit-breaker

Caution: Maintenance involves opening and closing circuit-breakers. Make sure that all safety notices are in place and allthe safety precautions taken.

Note: REB500 is still fully operational while the following main-tenance is being carried out.

The following example of performing a maintenance check on afeeder circuit-breaker assumes a double busbar configuration.


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Figure 8.8 Maintenance check on a feeder circuit-breaker

• The isolator image auxiliary supply must not be switched off.

• The feeder must not be grounded.

• The maintenance procedure must be gone through step bystep.

• The feeder is isolated from the busbars during the test andtherefore cannot conduct power.

The maintenance procedure for a feeder connected to doublebusbars is illustrated in Figure 8.9.


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Figure 8.9 Steps of the feeder maintenance procedure

8.3.3.1. Step 1

The conditions prior to maintenance can be seen from Figure8.10 “Configuration of the feeder before Step 1 (on load)”.

Figure 8.10 Configuration of the feeder before Step 1 (on load)

• Connect the PC to the central unit and start REBWIN.

• Open the circuit-breaker.


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• Close the circuit-breaker.

Check the statuses of the isolators and the circuit-breaker (pro-viding they are active in the protection system) in REBWIN byselecting “Switchgear objects” in the “View” menu (see Figure8.11 “Checking the statuses of the switchgear”).

Figure 8.11 Checking the statuses of the switchgear

• Interrupt the tripping circuit.


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8.3.3.2. Step 2

The conditions prior to Step 2 can be seen from Figure 8.12“Configuration of the feeder before Step 2”.

Figure 8.12 Configuration of the feeder before Step 2

• Short circuit the main c.t. leads at the terminals of the protec-tion cubicle and open the jumper to the protection.

• Inject a current of 1 x IN into each phase of the analogue in-puts.

• Read the current on the local control unit (see Section 8.1.3.“Viewing data on the local control unit (HMI)” or in REBWINby selecting “Analogue input measurements” in the “View”menu (see Figure 8.13. “Checking the currents at the analo-gue inputs”).


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Figure 8.13 Checking the currents at the analogue inputs

8.3.3.3. Step 3



• Start the REBWIN test generator in the “Test mode” dialo-gue. All the output relays are automatically blocked.

• Enable all the relays again so that the system is operatingnormally.


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• Trip trip circuit 1, R phase (see Figure 8.15 “Using the testgenerator to initiate tripping”).

Figure 8.15 Using the test generator to initiate tripping

• Check that the R phase pole of the circuit-breaker has trip-ped.

• Repeat the last two operations for the other phases and tripcircuits.

• Check that the circuit-breaker is open, otherwise open it.

• Check the remote tripping function of the breaker failureprotection if it is configured. The remote circuit-breaker mustbe ready to trip before this test. Make the transfer tripping cir-cuit. This must operate the remote tripping relay and trip theremote circuit-breaker. Check that this has indeed happened.

• Check the signals to other systems.


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8.3.3.4. Step 4



• Interrupt the transfer tripping circuit.

• Inject a current into the line protection (systems 1 and 2 if in-stalled).

• Check that the starting signal has been received from the lineprotection by the breaker failure protection. Use the “Binaryinput/output status” dialogue for this purpose (see Figure8.17 “Checking the binary inputs”).

• Remake the transfer tripping circuit.

The following test must also be performed if the busbar image ofthe circuit-breaker is being used:

• Close and reopen the circuit-breaker.

• Check the position of the circuit-breaker and the close com-mand in the “Binary input/output status” dialogue (see Figure8.17 “Checking the binary inputs”).


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Figure 8.17 Checking the binary inputs

8.3.3.5. Step 5



• Close and open the isolators to busbars 1 and 2.

• Check the positions of the isolators in the “Binary input/outputstatus” dialogue (see Figure 8.17 “Checking the binary in-puts”).


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8.3.3.6. Step 6



• Reinsert the jumpers in the c.t. secondary circuit and removethe short-circuit from the main c.t. leads.

• Close the isolator to connect the feeder to the desired bus-bars.


8.3.3.7. Step 7

The conditions prior to Step 7 can be seen from Figure 8.20“Configuration of the feeder before Step 7 (on load)”.

Figure 8.20 Configuration of the feeder before Step 7 (on load)

• Compare the actual load current with the value in the “Analo-gue input measurements” dialogue (see Figure 8.13“Checking the currents at the analogue inputs”).


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8.3.4. Example: Maintenance check on a bus-tie breaker

The maintenance procedure for a bus-tie breaker between a pairof double busbars is illustrated in Figure 8.21.

Figure 8.21 Steps of the bus-tie breaker maintenance procedure

8.3.4.1. Step 1

The conditions prior to maintenance can be seen from Figure8.22 “Configuration of the bus-tie breaker before Step 1 (onload)”.

Figure 8.22 Configuration of the bus-tie breaker before Step 1(on load)

• Connect the PC to the central unit and start REBWIN.

• Open the bus-tie breaker.


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• Open the isolators.

• If an overcurrent relay is connected to the same c.t’s in serieswith REB500, short circuit its current inputs.

8.3.4.2. Step 2

The conditions prior to Step 2 can be seen from Figure 8.23“Configuration of the bus-tie breaker before Step 2”.

Figure 8.23 Configuration of the bus-tie breaker before Step 2

• Short circuit the main c.t. leads at the terminals of the protec-tion cubicle and open the jumper to the protection.

• Completely block the busbar protection by applying the signal“32205_Block BBP” to the central unit.

• Inject a current of 1 x IN into each phase of the analogue in-puts.

• Read the current on the local control unit (see Section 8.1.3.“Viewing data on the local control unit (HMI)” or in REBWINby selecting “Analogue input measurements” in the “View”menu (see Figure 8.13. “Checking the currents at the analo-gue inputs”).

• Enable the busbar protection again.

8.3.4.3. Step 3


• Start the REBWIN test generator in the “Test mode” dialo-gue. All the output relays are automatically blocked.

• Enable all the relays again so that the system is operatingnormally.

• Close the bus-tie breaker.


8-36

• Trip trip circuit 1, R phase (see Figure 8.15 “Using the testgenerator to initiate tripping”).

• Check that the R phase pole of the circuit-breaker has trip-ped.

• Repeat the last two operations for the other phases and tripcircuits.

• Check that the bus-tie breaker is open, otherwise open it.

• Check the signals to other systems.

8.3.4.4. Step 4


• Remove the short-circuit across the overcurrent relay (if in-stalled).

• Inject a current into the overcurrent relay.

• Check that the starting signal has been received from theovercurrent relay by the breaker failure protection. Use the“Binary input/output status” dialogue for this purpose (seeFigure 8.17 “Checking the binary inputs”).

• Close and reopen the bus-tie breaker.

• Check the position of the bus-tie breaker and the close com-mand in the “Binary input/output status” dialogue (see Figure8.17 “Checking the binary inputs”).

8.3.4.5. Step 5


• Reinsert the jumpers in the c.t. secondary circuit and removethe short-circuit from the main c.t. leads.

• Close the isolators.

• Close the bus-tie breaker.

8.3.4.6. Step 6

The conditions prior to Step 6 can be seen from Figure 8.22“Configuration of the bus-tie breaker before Step 1 (on load)”.

• Compare the actual load current with the value in the “Analo-gue input measurements” dialogue (see Figure 8.13“Checking the currents at the analogue inputs”).


9-1

June 00

9. Fault-finding


9.2. Lists of possible faults ..............................................................9-39.2.1. General faults while starting the system...................................9-39.2.1.1. While starting the central unit ...................................................9-49.2.1.2. While starting the bay unit BU02..............................................9-79.2.1.3. While starting the REBWIN operator program .........................9-99.2.2. General faults in operation .....................................................9-109.2.3. System function failures .........................................................9-129.2.4. REBWIN errors ......................................................................9-179.2.5. Hardware failures ...................................................................9-199.2.5.1. 500CMP01/500CSP01/500CIM01 .........................................9-199.2.5.2. 500MBA01 .............................................................................9-209.2.5.3. 500SCM01 .............................................................................9-20

9.3. Replacing units.......................................................................9-229.3.1. Procedure ..............................................................................9-229.3.2. Replacing modules in the central unit ....................................9-239.3.3. Replacing a bay unit...............................................................9-249.3.4. Report ....................................................................................9-25

9.4. Restoring the system to operation..........................................9-25

9.5. Returning modules for repair..................................................9-25


9-2

9. Fault-finding


Caution: All work on the REB500 busbar protection systemmust be carefully planned. Errors when manipulating the systemcannot only destroy components, they can also cause falsetripping and serious interruption to the power supply.Modules that have been replace may only be repaired by themanufacturer.

Danger: Precautions must be taken in the immediate area whenworking on the central unit or one of the bay units to excludeany possibility of persons coming into contact with live parts. Adanger of electrical shock also exists when measuring currentsand voltages.

Danger: When replacing electronic modules, take thenecessary precautions to prevent damage to components dueto electrostatic discharge (ESD).


9-3

9.2. Lists of possible faults

The faults are divided into:

• faults during start-up

• faults during normal operation

9.2.1. General faults while starting the system

Faults are most likely to occur during installation of the protectionsystem (i.e. while testing and commissioning it).

Code Description Possible causes and corrective action

10 Unsuccessful central unitstart

Possible causes:1. Hardware

Corrective action:Step 1: Table 9.2 on Page 9-4

20 Unable to start bay unit Possible causes:Aux. supply failure

Corrective action:Step 1: Table 9.3 on Page 9-8

30 System blocked after start-up

Possible causes:1. Active isolator alarm during start-up2. Invalid event memory because of being

switched off longer than 24 hours or adefective power reservoir. Uploading toREBWIN can cause blocking.

Corrective action:Step 1: Check the voltage at the opto-

coupler inputs for the busbarimage isolator supervision.

Step 2: Acknowledge isolator alarm andthe system will start.

Step 3: Delete the event memory usingREBWIN and the system willstart.

60 System fails to respond. Nocaps fitted to unused500SCM01 channels.

Possible causes:1. Process bus failure

Corrective action:Step 1: Fit caps on unused 500SCM01

optocouplers.

Table 9.1 Starting the protection system


9-4

9.2.1.1. While starting the central unit


10 LED on PSM 03 not litalthough system switchedon

Possible causes:1. Aux. supply failure2. Fuse blown

Corrective action:Step 1: Check power supply.Step 2: Check fuse.

15 “Loading database” appearson the display and thesystem resets immediately

Possible causes:1. DBS (database) corrupted

Corrective action:Step 1: Delete database using REBTERM

terminal software and download thedatabase to the protection systemagain using REBWIN.

20 The central unit LED’s donot flash while starting.

Possible causes:1. Defective local control unit cable2. Defective local control unit3. IP Serial defective or missing4. Ribbon cable between MVME and TRM

defective or missing5. Firmware not installed.6. 500CMP01/500CSP01 monitor active

Corrective action:Step 1: Check the red LED’s on the back of

the rack (500CUB02 only). If anyare lit, the respective MVME’s arein the “Reset/Monitor mode”. Checkthat no external devices (PC ormodem) are communicating withREB500.

Step 2: Use REBLoad to check theREBSYS firmware.

Step 3: Check whether a Serial IP isinstalled.

Step 4: Check whether a Serial IP isinstalled and in the correct socket.

Step 5: Check that two ribbon cables gofrom the 500CMP01 to the TRM.

Step 6: Check the HMI cable and whetherit is plugged in the right connector.

Step 7: If the HMI is lit, the HMI cable is thewrong way round in the back planeconnector.

Step 8: The local control unit may also bedefective and has to be replaced.


9-5


40 The bus controllers fail torun within approx. 2 minutes

Possible causes:1. 500MBA01/500SCM012. Check jumper J1 on the

500CMP01/500CSP01Corrective action:Step 1: Check 500MBA01 according to

Table 9.15 on Page 9-20.Step 2: Check 500CSM01 according to

Table 9.16 on Page 9-21.Step 3: Check that jumper J1 is in place

on the 500 CMP01 (see Section 3).Step 4: Check that jumper J1 is not

inserted on the 500CSP01 (seeSection 3).

50 System does not respond Possible causes:1. Process bus failure2. No caps fitted on unused 500SCM01

channels

Corrective action:Step 1: Fit caps on unused 500SCM01

opto-couplers.

60 “Invalid 500SCM01configuration” displayed onthe local control unit

Possible causes:1. Wrong 500SCM01 configuration in the

500CMP01-500MBA01 settings2. The 500SCM01 modules are in the

wrong slots in the CU rack

Corrective action:Step 1: Check the 500SCM01 settings.Step 2: Check that the 500SCM01 is in

the correct slot.

65 System start-up stops asthe SIG subsystem starts

Possible causes:1. 500CSP01 or other modules configured

but not inserted

Corrective action:Step 1: Either insert the missing module

or deactivate it using REBWIN.

70 “Load database” isdisplayed on the HMI

Possible causes:1. No database available

Corrective action:Step 1: Download database to the

protection system usingREBWIN.

80 All the CU subsystems haveinitialised, but ITT_Readyand BBP_Ready do notappear in the event list

Possible causes:1. 500BIO01 is in the CU rack but

deactivated

Corrective action:Step 1: Remove 500BIO01.


9-6


100 The system resets as soonas it is started

Possible causes:1. The process bus is not operating

Corrective action:Step 1: Check that the cycling times on

the 500MBA01 and in thedatabase are the same.

Step 2: Check the device ID (99) and thenode_ID on the bus controller(see 500MBA01 settings).

Step 3: Check the 500SCM01configuration in the500CMP01/500MBA01 settings.

Step 4: Check the optical fibre linkbetween the bus controller500MBA01 and the 500SCM01.

Step 5: Check that two ribbon cables gofrom the 500CMP01 to the TRM.

Step 6: Check that one ribbon cable goesfrom the 500CSP01 to the TRM.

Step 7: Check that the TRM jumpersagree with the settinginstructions.

Step 8: 500CIM01 or 500CSP01 isinserted but deactivated

105 The system start-upprocedure stops at “Checkdatabase”

Possible causes:1. 500MBA01 incorrectly fitted

Corrective action:Step 1: Check that the 500MBA01’s are

in the correct slots (see SettingInstructions).

110 The CU 500BIO01’s haveinitialised, but are notwriting events in the eventlist.

Possible causes:1. 500BIO01 incorrectly configured

Corrective action:Step 1: Check the version of the

500BIO01 firmware usingREBLoad.

Step 2: Check the device and node ID’s.Step 3: Check that the binary inputs are

calibrated.Step 4: Check that the auxiliary supply

voltage is as given in thedatabase.

115 CU resets after TIM starts Possible causes:1. PBI defective

Corrective action:Step 1: Replace the PBI.


9-7


120 CU is ready and the bayunits can be switched on

Possible causes:1. CU is ready.

Corrective action:Step 1: Switch on the bay units.

Table 9.2 Starting the central unit

9.2.1.2. While starting the bay unit BU02


10 LED on PSM not lit althoughsystem switched on

Possible causes:1. Aux. supply failure2. Fuse blown

Corrective action:Step 1: Check power supply.Step 2: Check fuse.

20 The bay unit LED’s do notflash while starting.

Possible causes:1. Defective local control unit cable2. Defective local control unit

Corrective action:Step 1: Check the HMI cable.Step 2: The local control unit may also be

defective and have to bereplaced. Check in the CU eventlist whether it startedsuccessfully.

30 Bay unit does not start Possible causes:1. Optical fibre link defective2. Defective 500SCM013. Device/node ID incorrect

Corrective action:Step 1: Check the optical fibre link to the

CU.Step 2: Check that the optical fibre link

goes to the correct MVBsegment.

Step 3: Check that the 500SCM01channel and bay unit nodesagree.

Step 4: Check the BAP device and nodeID’s.

Step 5: Check the 500SCM01.

35 System signals “BBP startfailed”

Possible causes:1. Probably wrong DSP software version

loadedCorrective action:Step 1: Check DSP software version.


9-8


40 All the bay units of an MVBsegment do not start

Possible causes:1. Defective 500MBA012. Defective 500SCM013. Defective CPU

Corrective action:Step 1: Switch off all the bay units on the

respective segment.Step 2: Switch on the CU.Step 3: Check the CPU. The CU has

started correctly when LED1 andLED2 on the associated500MBA01 are lit. If not:- PBI defective- ribbon cable defective- TRM jumper incorrect

Step 4: Check the 500SCM01.

50 A bay unit resets afterstarting

Possible causes:1. Wrong device/node ID2. BU not calibrated3. Feeder deactivated but BU switched onCorrective action:Step 1: Check the device and node ID’s

on other units. Especially if a BAPhas been replaced, the device ornode ID may be wrong. Try toread the available binary andanalogue inputs on the BU andverify the results.

Step 2: Calibrate the inputs.Step 3: Check that the bay units of

deactivated feeders are switchedoff.

60 The bay units generate anisolator alarm

Possible causes:1. Wrong device/node ID2. Isolator/CB incorrectly connected3. Incorrectly calibrated binary inputsCorrective action:Step 1: Check the device and node ID’s.Step 2: Check that the auxiliary supply

voltage is as given in thedatabase.

Step 3: Check that the isolators andcircuit-breakers are correctlyconnected.

Step 4: Calibrate the binary inputs.

Table 9.3 Starting the bay units while starting the REBWINoperator program


9-9

9.2.1.3. While starting the REBWIN operator program


10 Communication cannot beestablished

Possible causes:1. COM port error2. IP Serial failure3. Defective ribbon cable4. Defective local control unit5. Defective serial cable

Corrective action:Step 1: Check that the correct COM port

is being used.Step 2: Check that no other application is

already using the COM port (e.g.the mouse).

Step 3: Check that the right cable isbeing used.

Step 4: Check that REB500 is in the“Ready” status for the REBWINlink.

Step 5: Check that IP Serial installed onthe 500CMP01 is runningproperly.

Step 6: Check that the two ribbon cablesbetween 500CMP01 and TRMare fitted.

Step 7: The local control unit has a serialinterface for the LCD and one fora PC. The latter may be faultyalthough the LCD works. Checkthe PC connection.

20 No events althoughconnected on-line

Possible causes:1. HMI sessions

Corrective action:Step 1: Delete all sessions.Step 2: Close REBWIN.Step 3: Restart REBWIN.

30 Only events from one bayunit

Possible causes:1. Probably connected to just one bay unit

Corrective action:Step 1: Close REBWIN.Step 2: Connect to CU.Step 3: Restart REBWIN.

Table 9.4 Starting the REBWIN operator program


9-10

9.2.2. General faults in operation

You may observe a fault, but cannot shut the system down (e.g.the system is selectively blocked). Check the signals and displayon the local control unit to see what is blocking the system.


10 System operating correctly Possible causes:1. Operating conditions

Corrective action:Step 1: No corrective action necessary.

20 The protection has tripped Possible causes:1. BBP2. BFP3. EFP4. OCDT5. PDF6. External trip

Corrective action:Step 1: Save events.Step 2: Save the fault.Step 3: Reset trips.Step 4: Inform the engineer responsible.

30 An alarm is generated Possible causes:1. Isolator image2. Differential current3. Hardware failure

Corrective action:Step 1: Save events.Step 2: Save the fault.Step 3: Proceed to the next failure (Code

40).

40 Differential current alarm Possible causes:1. C.t. or c.t. circuit fault2. Busbar image error3. Hardware failure

Corrective action:Step 1: Check the feeder currents (phase

relationship, see Section 8.1.6.2.“Differential current alarm”).

Step 2: Compare with the actual loadconditions.

Step 3: Verify the isolator positions.Step 4: Check that the correct isolator

contacts are in use and that Q1and +2 are not reversed.

Step 5: Check that both switch positionsare configured.

Step 6: Replace the bay unit.


9-11


50 Isolator alarm Possible causes:1. Incorrect isolator or circuit-breaker

auxiliary contact signals2. Auxiliary isolator supply failure

Corrective action:Step 1: Check the signal voltages at the

binary inputs and the positions ofthe isolator auxiliary contacts andcorrect as necessary.

60 Only general alarmgenerated

Possible causes:1. System or hardware failure2. SCS communication failure3. SCS time synchronisation4. Synchronisation period shorter than a

minute

Corrective action:Step 1: Replace CPU’s.Step 2: Replace the 500MBA01’s.Step 3: Check LON or IEC103

communication.Step 4: Change SCS time

synchronisation.

70 General alarm plus isolatoralarm on a bay unit

Possible causes:1. Communication failure

Corrective action:Step 1: Check the 500SCM01 according

to Table 9.16 on Page 9-21.Step 2: Check the 500MBA01 according

to Table 9.15 on Page 9-20.Step 3: Check the bay unit.

80 General alarm plus isolatoralarms on several bay units

Possible causes:1. Communication failure

Corrective action:Step 1: Check the 500SCM01 according

to Table 9.16 on Page 9-21.

Step 2: Check the 500MBA01 accordingto Table 9.15 on Page 9-20.

90 General alarm plus fanalarm

Possible causes:

1. Defective fan2. Fan power supply failure

Corrective action:Step 1: Check the fan power supply.Step 2: Replace the fan.


9-12


100 General alarm plus powersupply alarm (redundantpower supplies only)

Possible causes:

1. Defective power supply unit (PSU)

Corrective action:Step 1: Check whether the green LED on

the PSM03 is lit.Step 2: Check the station battery supply.Step 3: Check the fuse.

110 System restarts withoutreason (yellow LED flashesand the main menu isdisplayed on all the units)

Possible causes:1. The self-supervision function detected a

fault and restarted the system or thesystem detected a supply voltage failureand restarted itself.


Table 9.5 General faults in operation

9.2.3. System function failures

The following table gives explanations for most of the systemfunctions:


10 Bay unit fails to trip Possible causes:1. Function initiating the trip not active on

the particular bay unit2. Blocked tripping relay3. Tripping blocked by isolator or

differential current alarm4. Overcurrent check feature active and

fault current below pick-up5. Trip signal not assigned to the particular

bay (bay and bay unit are notnecessarily the same)

6. Bus-tie breaker with 2 c.t’s andintertripping failure (both c.t’s must beassigned to the same process bus)

7. The “Block output relays” command alsoblocks the protection functions in thebay units, e.g. breaker failure,overcurrent and end fault algorithms arenot processed.

Corrective action:Step 1: Check that the function initiating

tripping is active on the particularbay unit.

Step 2: Enable the tripping relays.Step 3: Check for an active differential

current alarm.


9-13


Step 4: Check for an active isolatoralarm.

Step 5: Check the overcurrent checkfeature.

Step 6: Check that the tripping commandgoes to the right bay unit.

Step 7: Check that both sets of c.t’s onthe bus-tie breaker are assignedto the same process bus.

Table 9.6 System function failures


30 Time synchronisation by theminute impulse does notfunction

Possible causes:1. Time synchronisation via IEC103 or

LON active (minute impulsesynchronisation does not function whenone of the two interbay bus protocols isconfigured)

Corrective action:Step 1: Delete the protocol from the

configuration if minute impulsesynchronisation is necessary.

40 OC and CR events viaIEC103

Possible causes:1. OC events (opto-coupler inputs

regardless of signals configured) andCR events (relay outputs regardless ofsignals configured) are not supported bythe generic IEC103 protocol and ifconfigured prevent the 500CIM01software from starting.

Corrective action:Step 1: Delete the IEC103 configuration

for the events.

50 500CIM01 resetssporadically

Possible causes:1. Defective LON

Corrective action:Step 1: Check LON bus and installproperly.

60 500CIM01 appears to startcorrectly but communicationfails

Possible causes:1. Defective 500CIM01

Corrective action:Step 1: Replace 500CIM01.

Table 9.7 500CIM01 failures


9-14


10 Instable differential current Possible causes:

1. Incorrect power system frequencysetting

Corrective action:

Step 1: Check the power systemfrequency setting using REBWIN.

20 Busbar protection fails totrip

Possible causes:

1. BBP function not activated2. BBP blocked by “Block BBP” input3. BBP blocked by an alarm4. Protection zone without c.t’s making

busbar protection impossible5. REB500 detects the circuit-breaker

status and any configured CLOSEcommand and the CB is between thec.t’s and the busbars.

Corrective action:

Step 1: Check that the BBP is activated.Step 2: Check the 500BIO01 input on the

CU.Step 3: Check that the BBP is not

blocked by the differential currentalarm.

Step 4: Check that an isolator alarm isnot preventing tripping.

Step 5: Verify the CB position.

30 Protection zonemeasurement producesinvalid values

Possible causes:

1. Protection zone without c.t’s makingbusbar protection impossible

2. BU not functioning

Corrective action:

Step 1: Check that the protection zonehas c.t’s.

Step 2: Check the alarm on the CU whichshows which BU’s are operatingand which are not.

30 Phase comparisonmeasurement fails to blockBBP

Possible causes:

1. Phase comparison algorithm inactivebecause the bay units are detecting lessthan 2 currents above the configuredpick-up setting.

Corrective action:

Step 1: No corrective action necessary.


9-15


30 Measurement always activeregardless of whethercircuit-breaker is open orclosed

Possible causes:

1. CB close command not configured andtherefore interpreted as active whetherthe aux. contact is open or closed andthe measurement is always active.

Corrective action:

Step 1: Configure the CB closecommand.

Table 9.8 Busbar protection failures


30 Trip fails Possible causes:1. BFP not activated in bay unit2. “Block output relays” is active and BFP

cannot operate3. Current below pick-up

Overcurrent check feature active and currenttoo low

End fault protection is a separate REB500protection function.

Corrective action:

Step 1: Activate BFP.Step 2: Check whether “Block output

relays” active.Step 3: Adjust the pick-up setting.Step 4: Verify the overcurrent check

feature.

Table 9.9 Breaker failure protection failures


9-16


30 Trip fails Possible causes:1. EFP not activated in bay unit2. “Block output relays” is active and EFP

cannot operate3. Current below pick-up4. Overcurrent check feature active and

current too low5. CB close command not configured and

therefore interpreted as active whetherthe aux. contact is open or closed andthe EFP function cannot be activated.

Corrective action:Step 1: Activate EFP.Step 2: Check whether “Block output


feature.Step 5: Configure the CB close

command.

Table 9.10 End fault protection failures


10 Trip fails Possible causes:1. PDF not activated in bay unit2. “Block output relays” is active and

PDF cannot operate3. Voltage below pick-up4. Overcurrent check feature active

and current too lowCorrective action:

Step 1: Activate PDF.Step 2: Check whether “Block output


feature.

Table 9.11 CB pole discrepancy function failures


9-17


50 Disturbance recorderfails to operate

Possible causes:1. Disturbance recorder deactivated

because last buffer register filledwhile reading disturbance recorderdata

Corrective action:Step 1: Activate disturbance recorder.

Table 9.12 Disturbance recorder failures

9.2.4. REBWIN errors

The REBWIN operator program can malfunction and generatethe following error messages:


102 Write_Session_Exist Possible causes:

1. Same function accessed by a secondPC (e.g. uploading events)

2. Connection between PC and protectionsystem terminated without closingREBWIN

Corrective action:Step 1: Wait until the session of the

second PC has been terminated.Step 2: Select “MMC session manager”

in the REBWIN “Tools” menu,close all sessions and restartREBWIN, making sure that noother PC is connected to theprotection system.

103 Invalid_Session Possible causes:

1. See Code 102

Corrective action:Step 1: See Code 102.

1004 TDB_Protocol_Error Possible causes:1. Communication failure or internal SW

error

Corrective action:Step 1: Check the connections to the

protection system.Step 2: Repeat the operation and consult

ABB should the problem persist.


9-18


1006 TDB_Buffer_Error Possible causes:1. Internal SW errorCorrective action:Step 1: Restart PC and REBWIN

operator program.Step 2: Repeat the operation and consult

ABB should the problem persist.

2002 TGR_Is_Busy Possible causes:1. Function not executedCorrective action:Step 1: Repeat execution of function.

2003 TGR_No_Session Possible causes:1. Forcing statuses only possible in test

mode

Corrective action:Step 1: Active test mode.

2004 TGR_Address_Not_Handled

Possible causes:1. Configuration data in database and

actual system configuration do notagree

Corrective action:Step 1: Check database in REBWIN

(correct station).2005 TGR_Configuration_Error Possible causes:

1. Invalid data in database

Corrective action:Step 1: Download database to the

protection system again.2006 TGR_Not_Responding Possible causes:

1. No connection between CU and BU2. System not ready (during start-up)3. Addressed unit switched off or defective

Corrective action:Step 1: Check optical link between CU

and BU.Step 2: Wait until system ready.Step 3: Check unit.

xxxx Possible causes:1. Internal software error

Corrective action:Step 1: Report failure to ABB.

Table 9.13 Error messages generated by the REBWINoperator program


9-19

9.2.5. Hardware failures

9.2.5.1. 500CMP01/500CSP01/500CIM01


10 LED’s lit as follows:

FAIL STAT

RUN SCON

SCSI VME

LAN FUSE

Possible causes:1. Unit operating properly


20 Red “Fail” LED lit:

FAIL STAT

RUN SCON

SCSI VME

LAN FUSE

Possible causes:1. Unit probably in monitor mode

Corrective action:Step 1: The respective MVME’s are in the

“Reset/Monitor mode”. Check thatno external devices (PC ormodem) are connected to orcommunicating with REB500.

Step 2: Reset system.Step 3: Replace unit if aboveunsuccessful.

30 “Fuse” LED lit:

FAIL STAT

RUN SCON

SCSI VME

LAN FUSE

Possible causes:1. Defective fuse

Corrective action:Step 1: No corrective action necessary as

fuse not used.

Table 9.14 500CMP01/500CSP01/500CIM01 failures


9-20

9.2.5.2. 500MBA01


10 LED’s 1 and 2 lit:

1 2

5 6

Possible causes:1. 500MBA01 operating properly


20 Only LED 1 lit:

1 2

5 6

Possible causes:1. Defective connection between

500MBA01 and 500SCM012. 500SCM01 not operating3. 500MBA01 not configured4. Defective 500MBA01

Corrective action:Step 1: Check connection between

500MBA01 and 500SCM01.Step 2: Check the 500SCM01 according

to Table 9.16 on Page 9-21.Step 3: Check 500MBA01 device and

node ID’s.

Table 9.15 500MBA01 failures

9.2.5.3. 500SCM01


10 All 500SCM01 LED’s lit:

1 2

9 10

Possible causes:1. Protection system operating properly


20 Only LED’s in right-handcolumn lit:

1 2

9 10

Possible causes:2. Corresponding 500MBA01 not

operating3. Defective connection between

500MBA01 and 500SCM014. 500SCM01 not configured5. 500SCM01 in wrong slot6. Associated Tx line interrupted7. Defective 500SCM01


9-21


Corrective action:Step 1: Check that the respective

500MBA01 is operating.Step 2: Check connection between

500MBA01 and 500SCM01.Step 3: Configure the 500SCM01.Step 4: Check the 500SCM01 slot and

correct as necessary.Step 5: If only some of the LED’s in the

left-hand column are not lit, onlysome of the channels aredefective and therefore attempt touse any serviceable channelsthat are available.

Step 6: Replace the 500SCM01.

30 Only LED’s in left-handcolumn lit:

1 2

9 10

Possible causes:1. Corresponding channel not used2. Corresponding BU not connected3. Corresponding BU switched off4. Optical fibre link to BU interrupted5. Associated Rx line interrupted

Corrective action:Step 1: None if channel indeed not used.Step 2: Check BU connection.Step 3: Switch BU on.Step 4: Check the optical fibre link.Step 5: Attempt to use a serviceable Rx

channel that is available.Step 6: Replace the 500SCM01.

60 All LED’s flicker Possible causes:1. Defective 500SCM01

Corrective action:Step 1: Replace the 500SCM01.

70 Process bus failure Possible causes:1. Caps missing from unused channels

Corrective action:Step 1: Check caps on unused channels

and fit as necessary.

Table 9.16 500SCM01 failures


9-22

9.3. Replacing units

Caution: Units and modules may only be replaced with thepermission of the engineer responsible for the protectionsystem.

9.3.1. Procedure

The best time to replace assemblies is when the station is out ofoperation, but even in this case, care must be taken that nounintentional operation of switchgear can take place (danger topersons close to the item of plant).

While the station is in operation, care must be taken that thestation is still adequately protected when REB500 is switchedoff.

Caution: Power supply units may never be inserted orwithdrawn with the auxiliary supply connected. Therefore placethe switch on the front of the power supply unit in the off positionand unplug the green connector on the end of the battery cable.It is insufficient to simply switch off the unit.

The other modules may only be inserted or withdrawn when theswitch on the front of the power supply unit 500PSM03 in the offposition or there is no power supply unit fitted.


9-23

9.3.2. Replacing modules in the central unit

Slot

Module Backplane500CUB01

ID = 2

Backplane500CUB02

ID = 5

500PSM03 1 1

500PSM03 3 20

500CMP04 5 4

500TRM02/500MBA01 6 5

500CSP04(1) 7 7

500TRM02 / 500MBA01 / 500SCM01 8 8

500CSP04(2) 9 10

500TRM02 / 500MBA01 / 500SCM01 10 11

500CSP04(3) 11 --

500TRM02 / 500MBA01 / 500SCM01 12 12

500CSP04(4) 13 --

500TRM02 / 500MBA01 / 500SCM01 14 15

500CSP04(5) / 500CIM04 15 13

500TRM02/03 / 500MBA01 / 500SCM01 16 14

500MBA01 / 500SCM01 17 16

500MBA01 / 500SCM01 18 17

500BIO01 / 500MBA01 / 500SCM01 19 18

500BIO01 20 19

After replacing a 500CMP04, 500CSP04, 500CIM04, 500MBA01or 500BIO01 module, it is necessary to reconfigure thecommunication addresses (device and node ID’s). Thecorresponding procedure is as follows:

1 Switch off the CU.

2 Connect a PC to the LHMI on the CU.

3 Start the REBLoad program which is in the same directory asREBWIN.

4 Select “Open project database” in the “File” menu and loadthe system configuration file.


9-24

Figure 9.1 System configuration file dialogue5 Click on the <Check> button, after which REBLoad waits for

communication to be established with the CU.

6 Switch on the REB500 CU.

7 REBLoad checks the CU configuration on the basis of thesystem configuration file. Correctly configured boards appeargreen and incorrectly configured boards red.

8 Click on the <Start> button to completely reconfigure the CU.

9 Refer to Section 9.4. “Restoring the system to operation” forthe remainder of the procedure.

9.3.3. Replacing a bay unit

After replacing a bay unit it is only necessary to reconfigure thedevice and node ID’s (see Section 8.3.2. “Replacing a bay unit”).


9-25

9.3.4. Report

Record all modules that are replaced in a report and update thereport every time a module is replaced.

9.4. Restoring the system to operation

Caution: The protection system may only be restored tooperation with the permission of the engineer responsible for it.

The protection system starts and initialises automatically whenthe power supply unit is switched on.

9.5. Returning modules for repair

Defective modules should be shipped accompanied by a fulldescription of the failure, wherever possible in the originalpacking or in packing that affords adequate protection frommoisture, vibration and electrostatic discharge to your ABBcompany or agent or to the following address:

ABB Power Automation Ltd.,Haselstrasse 16/122CH-5401 BadenSwitzerland


10-1

June 00

10. Storage, decommissioning and disposal

10.1. Safety instructions..................................................................10-2

10.2. Storage ..................................................................................10-2

10.3. Decommissioning...................................................................10-210.3.1. Switching off...........................................................................10-210.3.2. Disconnecting the instrument transformers............................10-310.3.3. Disconnecting auxiliary circuits ..............................................10-310.3.4. Dismantling ............................................................................10-3

10.4. Disposal .................................................................................10-3


10-2

10. Storage, decommissioning and disposal


Caution: Before removing REB500 from operation, make surethat the station is adequately protected by other protection devi-ces and systems.

Caution: After REB500 has been removed from operation, sur-rounding items of plant may still be live. Therefore take the ne-cessary precautions to make the working area safe.

10.2. Storage

The equipment may never be stored outdoors. The protectioncubicle and other components must be stored in a clean, dry,closed room which is not subject to wide fluctuations of tempe-rature.

The equipment packing is designed for a certain maximum sto-rage period. The original packing must be replaced or at leastthe desiccate in the packing checked and replaced if necessaryshould the maximum storage period is exceeded. Special long-term storage packing includes hygrometers which are visiblethrough openings.

The permissible storage temperature range is –40 °C to +85 °C.

Refer to the general ABB documentation for detailed storage in-structions.

10.3. Decommissioning

Danger: When designing the station, it must be taken into ac-count that the REB500 system can be switched off. REB500may also be connected to other protection systems and the ab-sence of its output signals may cause them to trip and open cir-cuit-breakers unintentionally.

10.3.1. Switching off

To switch off the REB500 system, place the switches on the po-wer supply units in the central unit and the bay units in the offposition and withdraw the green power supply connectors.


10-3

10.3.2. Disconnecting the instrument transformers

C.t’s

Danger: C.t. circuits must never by open-circuit. When discon-necting the REB500 input circuits from the c.t’s, the main c.t.circuits must be short-circuited first at the isolating and shortingterminals.

Even when the whole station is switched off, c.t. circuits shouldnever be left open-circuit.

V.t’s

Danger: When the station is in operation, there is a dangerousvoltage across the v.t’s. Therefore use appropriately insulatedtools to open the v.t. circuits. The connections to the v.t’s mustbe correspondingly insulated and may never be short-circuited.

Even when the whole station is switched off, take care when dis-connecting v.t. circuits and insulate the connections.

10.3.3. Disconnecting auxiliary circuits

Disconnect the auxiliary circuits (signal inputs and outputs, trip-ping circuits) one at a time and insulate each one. Dangerousvoltages may also be involved in this case as well (signal voltagerange 36 V to 312 V).

10.3.4. Dismantling

The central unit and bay unit equipment racks and housings canbe removed from the cubicles, after which the cubicles can alsobe removed.

Danger: When the station is in operation, make sure that thereis an adequate safety distance to live parts, especially as dis-mantling is often performed by unskilled personnel.

10.4. Disposal

Observe local regulations concerning the disposal of electricalwaste.


10-4

We recommend removing the boards from the racks. The hou-sings and cubicles can then be disposed of as old iron and onlythe boards as electrical waste.

Remove any NiCd batteries from the boards and dispose ofthem separately as batteries.

REB 500 1MRB520259-Uen / Mod. A ABB Power Automation Ltd

11-1

June 2000

11. Options

11.1. Breaker back-up protection ....................................................11-311.1.1. Function of the breaker back-up protection............................11-311.1.2. Available signals for the breaker back-up protection..............11-511.1.3. Configuration of the breaker back-up protection ....................11-711.1.3.1. Breaker back-up protection in stations

equipped with an bypass busbar............................................11-911.1.3.2. Trip redirection .......................................................................11-911.1.3.3. Current setting......................................................................11-1011.1.3.4. Grading a two-stage breaker back-up protection .................11-1211.1.3.5. Grading a one-stage breaker back-up protection.................11-1511.1.3.6. Logic type.............................................................................11-15

11.2. End fault protection ..............................................................11-1611.2.1. Function of end fault protection............................................11-1611.2.2. Available signals for end fault protection..............................11-1811.2.3. Configuration of the end fault protection ..............................11-19

11.3. Time-overcurrent protection .................................................11-2011.3.1. Time-overcurrent protection function....................................11-2011.3.2. Available signals for time-overcurrent protection..................11-2111.3.3. Configuration of time-overcurrent protection ........................11-22

11.4. Circuit breaker pole discrepancy protection .........................11-2411.4.1. Circuit breaker pole discrepancy protection function............11-2411.4.2. Available signals for circuit breaker

pole discrepancy protection .................................................11-2511.4.3. Configuration of the circuit breaker

pole discrepancy protection .................................................11-26

11.5. Extended disturbance recorder ............................................11-2811.5.1. Function of the extended disturbance recorder....................11-2811.5.2. Available signals for the expanded disturbance recorder.....11-28

11.6. Release of the trip command ...............................................11-3011.6.1. Release of trip through internal undervoltage function .........11-3211.6.1.1. Configuration - voltage transformer......................................11-3311.6.2. Release of trip with the aid of external enabling input

"31805_External release BB-zone" ......................................11-3411.6.3. Overcurrent release of the trip command.............................11-34

ABB Power Automation Ltd REB 500 1MRB520259-Uen / Mod. A

11-2

11.7. Neutral current measurement ..............................................11-3611.7.1. Function of neutral current measurement ............................11-3911.7.2. Configuration of neutral current measurement.....................11-3911.7.3. Calculations and verification ................................................11-4011.7.3.1. Calculating the total burden PB............................................11-4011.7.3.2. Calculating the actual overcurrent factor n' ..........................11-4011.7.3.3. Checking the stability in the case of an external fault...........11-4111.7.3.4. Calculating the setting of IKmin............................................11-4111.7.3.5. Checking the trip action in the case of busbar short circuit

(ground fault)........................................................................11-4111.7.3.6. Example ...............................................................................11-42

11.8. Interbay bus (IBB) connection..............................................11-4511.8.1. Introduction ..........................................................................11-4511.8.2. Hardware..............................................................................11-4611.8.2.1. Basic components................................................................11-4611.8.2.2. LON hardware configuration ................................................11-4811.8.2.3. IEC 60870-5-103 hardware configuration ............................11-4911.8.3. Common IBB functions ........................................................11-5011.8.3.1. Basic IBB configuration ........................................................11-5011.8.3.2. REB500 event configuration ................................................11-5211.8.3.3. Transfer of differential current values...................................11-5311.8.4. LON......................................................................................11-5511.8.4.1. Installing a LON node...........................................................11-5511.8.4.2. Addressing ...........................................................................11-5611.8.4.3. Configuration........................................................................11-5711.8.4.4. Commands via the LON IBB ................................................11-5911.8.4.5. Displaying status information (events) .................................11-5911.8.5. IEC 60870-5-103..................................................................11-6511.8.5.1. Introduction ..........................................................................11-6511.8.5.2. General functions .................................................................11-6511.8.5.3. Disturbance recorder............................................................11-6811.8.5.4. Generic REB500 functions...................................................11-6811.8.5.5. Special information and instructions for configuring

the control system................................................................11-76

11.9. Interfaces .............................................................................11-7911.9.1. Serial interfaces (RS 232) ....................................................11-7911.9.2. Fibre optic connection ..........................................................11-7911.9.3. Modem connection...............................................................11-8011.9.3.1. Remote access via modem..................................................11-80


11-3

11. Options

The following protection functions can be integrated into REB500as options:

11.1. Breaker back-up protection

11.1.1. Function of the breaker back-up protection

The circuit breaker is the last and most important link in theprotection chain. The purpose of the breaker backup protectionis to take the right action should the circuit-breaker fail toexecute the trip command. This involves tripping the nearestcircuit breakers surrounding the fault, which are mainly in thesame station may also include one at the remote end of a line(intertripping).

The principle of the breaker backup protection function is basedon monitoring the time the fault persists after a trip commandhas been issued to the circuit breaker and it has been enabledby the main protection.

The breaker backup protection function can be enabled phase-selectively via two separate inputs. All three phases can beenabled via up to 6 different inputs and the currents of all threephases monitored. Operation of the breaker backup protectioncan alternatively be enabled by an internal time-overcurrentfunction (by selecting the appropriate logic using the REBWINoperator program) and a trip command from the busbarprotection.

The internal signals are shown on a grey background in theblock diagram of the breaker backup protection (Figure 11.1).The inputs are on the left and the outputs on the right. The inputsignal is a tripping signal generated by the central unit that wasinitiated by the busbar intertripping function (BBP, BFP t2 etc.)


11-4

& & & &

&&

&

&

&&

1RS

II

>

setti

ng

II

>

setti

ng

II

>

setti

ng

I

>

setti

ng

1110

5_Ex

tern

al T

RIP

OC

DT_

trip

PDF_

trip

Trip

-inte

rtrip

1374

0_ L

1L2L

3/1

Star

t BFP

1376

5_ L

1L2L

3/6

Star

t BFP

1376

0_ L

1L2L

3/5

Star

t BFP

1375

5_ L

1L2L

3/4

Star

t BFP

1375

0_ L

1L2L

3/3

Star

t BFP

1374

5_ L

1L2L

3/2

Star

t BFP

1373

5_ L

1/2

Star

t BFP

1373

0_ L

1/1

Star

t BFP

1372

5_ L

1/2

Star

t BFP

1372

0_ L

1/1

Star

t BFP

1371

5_ L

1/2

Star

t BFP

1371

0_ L

1/1

Star

t BFP

Tim

er t1

act

ive

Tim

er t2

act

ive

1370

5_Ex

tern

al S

tart

BFP

113

205_

(BU

)Bl

ock

BFP

3321

0_ (C

U)

Bloc

k BF

P

1) T

his

switc

h is

clo

sed

in V

ersi

on o

f the

logi

c

2) S

et b

y m

eans

of t

he R

EBW

IN o

pera

tor p

rogr

am

3) P

ay a

ttent

ion

to th

e tra

nsfe

r trip

func

tion

4) F

or th

e Lo

gic,

ver

sion

4, o

verri

ding

the

timer

t2

Tim

er t1

Tim

er t1

Tim

er t1

Tim

er t1

2331

5_BF

P tr

ip L

1

2332

0_BF

P tr

ip L

2

2332

5_BF

P tr

ip L

3

BFP

bloc

ked

2) off

3) 3)

Tran

sfer

trip

impu

lse

wid

th 2311

0_BF

P re

mot

e TR

IP

2340

5_BF

P bl

ocke

d

4340

5_BF

P bl

ocke

d

4331

0_BF

P tri

p t2

(CU

)

Inte

rtrip

2331

0_BF

P tri

p t2

2333

5_Tr

ip b

y BF

P

4330

5_BF

P tr

ip t1

(CU

)

2330

5_BF

P tr

ip t1

2310

5_BF

P T

RIP

4)

1)

HEST 985010 C

L1 L2 L3

L1 L2 L3 MAX

(L1,

L2,

L3)

Tim

er t2

Figure 11.1 Block diagram of the breaker backup protection(logic type 1)


11-5

The following internal REB500 functions can start the breakerfailure function in all three phases:

• Busbar protection function

• An external trip command

• Time-overcurrent, providing logic 3 is configured

• Circuit breaker pole discrepancy protection, providing logic 3is configured.

11.1.2. Available signals for the breaker back-up protection

Binary input signals

Remarks Signalresponse

Disturb. rec.:Trigger?Record?

33210_Block BFP BFP Slow no

Table 11.1 Binary inputs on the central unit

Signalresponse

Used fordisturbance rec.:

Trigger?Record?

13205_Block BFP fast yes

13605_Trip transferred slow yes

13705_External start BFP fast yes

13710_Start BFP Lp/x13715…13735

fast yes

13740_Start BFP L1L2L3/x13745…13765

fast yes

Table 11.2 Binary inputs on the bay units


11-6

Binary output signals

Display on localcontrol panel

Signaltype

Configure onn BIO module


Trigger?Record?

43305_BFP trip t1 <Date / Time >BFP trip T1Bay unit xred

S 2 no

43310_BFP trip t2 <Date / Time >BFP trip T2Bay unit xred

S 2 no

43405_BFP blocked BFP blocked *)Flashes yellow

S 2 no

Table 11.3 Binary output signals on the central unit

Protectionfunction

Display onlocal control

panel

Signaltype

Configureon n BIOmodule

Used fordisturb.

rec.:Trigger?Record?

23105_BFP TRIP BFP <Date / Time >BFP trip T1Red

T 2 TR, R

23110_BFP remoteTRIP

BFP None S 2 TR, R

23305_BFP trip t1 BFP <Date / Time >BFP trip T1Red

S 1 TR, R

23310_BFP trip t2 BFP <Date / Time >BFP trip T2red

S 1 TR, R

23315_BFP trip L1 BFP BFP trip L1Red

S 1 TR, R


S 1 TR, R


S 1 TR, R

23330_Triptransferred

all none S 1 TR, R


11-7

Protectionfunction


panel

Signaltype


Used fordisturb.


23335_Trip by BFP BFP none T 1 TR, R

23405_BFP blocked BFP BFP blockedFlashes yellow

S 1 TR, R

Table 11.4 Binary outputs on the bay units

11.1.3. Configuration of the breaker back-up protection

The breaker backup protection has two adjustable timers. At theend of time t1, a second attempt is made to trip the breaker,which has failed, to trip; at the end of time t2 the surroundingbreakers are tripped. A transfer-tripping signal to the remotestation generated either at the end of time t1 or t2 can also beenabled using the REBWIN operator program.

The currents of the three phases are measured individually andcompared with the pick-up setting, which is identical for the threephases. The timers can also be started independently of theovercurrent check and the main protection inputs via an externalinput (signal “13705_Ext. Start BFP”).

For safety reasons, a normally-open auxiliary contact on thecircuit breaker should be connected in series with the externalcontrol signal applied to this input.

Since there are three separate t1 timers for the individualphases, the REB500 breaker backup protection respondscorrectly to an evolving fault.

Logic 4 can be used in stations with 2 redundant REB500 units,one for busbar and the other for breaker failure protection. In thiscase, the special input “13765_Start BFP L1L2L3_6” on theREB500 for breaker failure protection is used to instantly initiateintertripping after t1 independently of the time setting of t2.


11-8


BFP active inactive

Setting (per currenttransformer)

0,1 2,0 1,2 0,1 IN

Timer 1 active active

Timer 2 active active

Timer t1 10 5000 100 10 ms

Timer t2 0 5000 150 10 ms

Intertripping pulseduration

100 2000 200 10 ms

Logic type 1 4 1 1

Table 11.5 Parameters for setting breaker back-up protection

Detail

Figure 11.2 Breaker back-up protection

In the “Detail” view , the breaker back-up protection can beactivated per bay:Intertripping (remote trip) can be applied after completion ofeither timer t1 or t2.


11-9

For a description of the different logic types, see Section11.1.3.6 Logic type.

11.1.3.1. Breaker back-up protection in stations equipped with anbypass busbar

Where the busbar system includes a bypass busbar and thebreaker back-up function in bay unit BU_0 is excited by anexternal signal, bay unit BU_0 trips the whole busbar 2 in theabove diagram instead of just circuit breaker Q9. This can beprevented if the circuit breaker Q9 in bay unit BU_9 has its owncurrent transformer.

Q0

Busbar 1Busbar 2

Bypass busbar

BU_0 BU_9

Q9

Figure 11.3 Bypass busbar

11.1.3.2. Trip redirection

If a circuit breaker is unable to trip (e.g. air pressure to low), thetrip redirection function redirects its trip signal to other circuitbreakers. The trip redirection function is basically independent ofthe breaker failure protection, but uses the intertripping outputsignal “23110_BFP” and the trip by BFP signal “23335_Trip byBFP”.

A low-current check feature can be configured for the trip redi-rection function so that redirection only takes place when the re-spective feeder is conduction a certain current. The overcurrentcheck feature is used for this purpose (regardless of whether it isotherwise configured or not).

Providing the trip redirection function is active, a trippingcommand is not issued locally to the circuit breaker in question.


11-10

HEST 985035 C

& &

I > ettings

I > setting

I > ettings

L1

L2

L3

IL1

IL2

IL3

23110_BFP intertrip

23335_Trip by BFP

Intertrip (CU)

BFP Trip (internal)

OCDT Trip (internal)

PDF Trip (internal)

BBP TRIP (internal)

11105_EXT.TRIP

13605_Trip redirection

Figure 11.4 Trip redirection

11.1.3.3. Current setting

If the pick-up current of the breaker backup function is set toolow there is a risk that the breaker backup protection will notreset quickly enough after a circuit breaker has beensuccessfully tripped. This can be the result of decayingoscillations in the c.t. secondary circuit.

Conversely the breaker backup protection may fail to operate ifthe setting is too high. This situation could arise, for example,due to severe c.t. saturation when the secondary current fallsbelow the setting and the breaker backup protection resets.Recommendations now follow which enable the pick-up currentof the breaker backup protection to be correctly set in relation tothe c.t. data (n') and the set time.

Basically, the current setting (IE) should be less than theminimum fault current IKmin of the corresponding feeder. Just tosatisfy this condition, the setting would be:

N

minK

N

EII8.0

II ⋅=

This setting may be too high for conventional iron core c.t’sbecause the measurement may not function correctly even atlow fault currents due to transient components in the faultcurrent. A failure of the breaker to operate will always bedetected, but tripping could be delayed.


11-11

Iron core transformers (Class TPX) and transformers withresidual flux “air gap” (Class TPY)

It is necessary to know the transient overcurrent factor (n*) inorder to design a scheme for operation with these c.t’s. This iscalculated from the effective overcurrent factor n' as follows:

EB

ENPPPPn'n

++⋅=

NTf21'n*n

⋅⋅+= ⋅π

After obtaining the transient overcurrent factor (n*), the settingsare given by:

a) Assuming N

minKII8.0*n ⋅< ,

the current setting is *nIIN

E ≤

b) Assuming N

minKII8.0*n ⋅> ,

the current setting is ≤N

EII

N

KminII0.8 ⋅

Note: TPX and TPY transformers differ, in respect of transientcharacteristics, by a small remanence in the case of the TPYtype. With regard to transient over-dimensioning, TPX and TPYhardly differ.


11-12

Calculation example

C.t. data:Ratio 600/5 ARated burden PN 15 VALosses PE 7 VARated overcurrent factor n 20

Lead burden: 10 VA

Bay unit burden: < 0.1 VA

Rated frequency f: 50 HzPower system time constant TN: 80 ms

Minimum fault current IKmin: 450 A

88.25VA7VA10VA7VA1520'n =

++⋅=

99.0s08.0

s15021

88.25*n =⋅⋅⋅+

=π

Since 6.0A060

A4508.0II8.099.0*nN

minK =⋅=⋅>= ,

the setting becomes N

minK

N

EII8.0

II ⋅≤ , i.e. IE = 0.5 IN

Linearised current transformers (TPZ)

Since these c.t’s are scarcely subject to saturation, the setting isonly based on the minimum fault current for the feeder:

N

minK

N

EII8.0

II ⋅=

11.1.3.4. Grading a two-stage breaker back-up protection

Timer t1 is started 33 ms after the breaker backup protectionreceives a starting signal from the main protection. A secondattempt is made to trip the circuit breaker and the timer t2 isstarted at the end of the set time t1. Should the circuit breakeragain fail to trip within the set time of t2, the surroundingbreakers are intertripped.

Intertripping to the opposing side can be configured aftercompletion of timer t1 as well as after t2.


11-13

Minimum setting:

Minimum setting for t1 t1 > tCB + 18 ms + tRes

Minimum setting for t2 t2 > ta+ tCB + 18 ms + tRes

Maximum tripping time t1(at min. setting of t1)

tCB + 18 ms + tRes + ta

Maximum tripping time t2(at min. setting of t1 and t2)

2 * (tCB + 56 ms)

where tCB = circuit-breaker operating time plus arc ignition time

ABB Power Automation Ltd. recommends an additional marginof 20 ms on the above minimum settings.

Caution: The correct operation of the breaker back-upprotection can only be ensured when the above mentionedminimal time-settings are adhered to.

Example:

The minimum setting for t1 with a circuit breaker operating time(tCB) of 40ms is:

tCB + 18 ms + tRes = 40 + 18 + 20 = 78 ms.

That results in a maximum tripping time of :

tCB + 18 ms + tRes + ta = 40 + 18 + 20 + 22 = 100 ms.


11-14

t

Backup protection start (main protection trip)

Measurement by main protection

Start of fault

Second attempt to trip circuit-breaker

Trip bus section(intertripping)

t t

t

t t

ttt ttt

e

1 2a a

CB CBV marg margV

Figure 11.5 Breaker back-up protection time grading

Legend:

t1 timer t1

t2 timer t2

ta delay time between timing stage and trip command (max. 22ms)

tCB circuit-breaker tripping time plus arc extinction time

tV reset time of current measurement *)

tmarg safety margin (>20 ms, general safety margin)

The above sequence (Figure 11.5) only runs all the way throughif the circuit breaker has failed. Should the starting signal fromthe main protection disappear or the breaker backup protection’sown current measurement reset during the course of t1 or t2, thesequence is discontinued and the timer in question resets.

The commands issued by the timers t1 and t2 cannot beexecuted if the timers are not started and run to the end of theirset times.

Setting the timer t1 or t2 to 0 ms means that the correspondingfunction is executed as soon as the starting conditions arefulfilled.


11-15

The recommended minimum settings for t1 and t2 are necessaryto allow time for the busbar protection to reset after the circuitbreaker has opened.

*) This reset time is 18 ms and is not to be confused with thereset time from the data sheet. This refers to the reset of theoutput relay after the current decays after a successful trip to “0”.

11.1.3.5. Grading a one-stage breaker back-up protection

A one-stage breaker backup protection is achieved by settingtimer t2 to zero. Providing the starting conditions are fulfilled, thecurrent check function is picked up and time t1 has expired, tripsignals go to the bay’s own breaker, the surrounding breakersand via a transfer tripping channel to the remote end of thefeeder.

11.1.3.6. Logic type

The internal breaker back-up protection can be changed forspecial applications. The breaker back-up protection schemedescribed here, is the logic-type 1.

Alternative logics:

2. Reserved for special applications, no description available.

3. The breaker failure protection can also be started by thetripping signals from the time-overcurrent and circuitbreaker pole discrepancy protections. Otherwise logic type3 corresponds to type 1.

4. The signal “13765_Start BFP L1L2L3_6” initiates, after BFPt1 irrespective of the setting for BFP t2, an intertripping.Otherwise logic type 4 corresponds to type 1.


11-16

11.2. End fault protection

11.2.1. Function of end fault protection

The end fault protection detects faults between a circuit breakerand the c.t’s which cannot be cleared by the busbar protectionon its own.

I > EFP setting

I > EFP setting

34215_Block EFP (CU)

14205_Block EFP

1

I > EFP setting


44305_EFP trip (CU)

EFP blocked

24405_EFP blocked

44405_EFP blocked (CU)

EFP timer

CB close command

t 0

&(36 ms)0

24305_EFP trip

1)

1)

1)

1) EFP = end zone fault Typical setting 1.2 I when engineering scheme

Pick-up delay

2) The signal "EFP remote TRIP" is available for transfer tripping. Its duration can be set using the operator program under Settings/System response.

CB "OPEN" auxiliary contactCLOSE

coil&

2)Intertripping pulsewidth

L1

L2

L3

N

Figure 11.6 Block diagram of the end fault protection with thecurrent transformers on the line side


11-17

34215_Block EFP (CU)

14205_Block EFP

I > EFP setting 1

I > EFP setting

I > EFP setting


44305_EFP trip (CU)

EFP blocked

24405_EFP blocked

44405_EFP blocked (CU)

EFP timer

CB close command

t 0

&(36 ms)0

24305_EFP trip

1)

1)

1)

1) EFP = end zone fault Typical setting 1.2 I when engineering schemeN

Pick-up delay

CB "OPEN" auxiliary contactCLOSE

coil

EFP intertrip

&

L1

L2

L3

N

Figure 11.7 Block diagram of the end fault protection with thecurrent transformers on the busbar side

To ensure that the end fault protection bases its decision on aneffective image of the circuit breaker status, the signal “circuitbreaker open” is delayed while the circuit breaker is actuallyopening. If a current is measured when the circuit breaker isopen, a tripping command is issued after a further delay (set to36 ms). The purpose of this timer is to enable a circuit breakerclose command to be detected that is subject to internal signaltransit times and breaker contact bounce times.


11-18

11.2.2. Available signals for end fault protection



Disturbancerec.: Trigger?

Record?

34215_Block. PZM PZM slow no


Signalresponse


Record?

14205_Block. PZM fast yes

Table 11.7 Binary inputs on the bay unit



Signaltype



Trigger?Record?

44305_trip PZM <Date / Time >trip PZMBay unit xRed

M 2 no

44405_PZM blocked PZM blocked *)Flashes yellow

M 2 no

Table 11.8 Binary outputs on the central unit

Protectionfunction


panel

Signaltype


Distur-bancerec.:

Trigger ?Record?

24105_PZM RemoteTRIP

PZM <Date / Time >PZM tripRed

M 2 TR, R

24305_PZM trip PZM <Date / Time>PZM tripRed

M 1 TR, R

24405_PZM blocked PZM PZM blockedFlashes yellow

M 1 TR, R



11-19

11.2.3. Configuration of the end fault protection

The following parameters can be set for the end fault protectionusing the REBWIN operator program:


EZP active inactive

Pick-up delay 0.1 10.0 0.4 0.1 S

Pick-up setting 0.1 2.0 1.2 0.1 IN

Table 11.10 Parameters for setting end fault protection

To avoid false tripping after the circuit-breaker has opened, thedelay for the end fault protection must be set longer than the twotimer stages of the breaker backup protection (i.e. > timer t1 +timer t2).

All bays are listed in the overview.

Detail

Figure 11.8 End fault protection

In the detail view, the end fault protection per bay can beactivated and the on delay can be set. (This on delay only hasmeaning with the opening of the circuit breaker.)


11-20

11.3. Time-overcurrent protection

11.3.1. Time-overcurrent protection function

The time-overcurrent function operates entirely independently ofthe other protection functions in each of the bay units

35220_Block OCDT (CU)

15210_Block OCDT

I > setting 1

I > setting

I > setting

I < setting * RR

I < setting * RR

I < setting * RR

45805_OCDT Start (CU)

25105_OCDT TRIP

25305_OCDT trip

43305_OCDT trip (CU)

OCDT blocked

25405_OCDT blocked

45405_OCDT blocked (CU)

OCDT delay

1)

1)

1)

1) RR = reset ratio (OCDT) Typical setting 0.95 when engineering scheme

R

STimer

&

L1

L2

L3

L1

L2

L3

Figure 11.9 Block diagram of the time-overcurrent function

The time-overcurrent function does not intertrip the respectivebusbar protection zone.


11-21

11.3.2. Available signals for time-overcurrent protection



Record?

35220_OCDT blocked OCDT slow no


Signalresponse


Trigger?Record?

15210_OCDT blocked fast yes




Signaltype



Trigger?Record?

45305_OCDT trip <Date / Time >OCDT tripBay unit xRed

S 2 no

45405_OCDT blocked OCDT blocked *)Flashes yellow

S 2 no

45805_OCDT start None S 2 no



11-22

Protectionfunction


Signaltype


Dis-turbance


25105_OCDT TRIP OCDT <Date / Time >IMAX tripRed

T 2 TR, R

25305_OCDT trip OCDT <Date / Time >IMAX tripRed

S 1 TR, R

25405_OCDTblocked

OCDT OCDT blockedFlashes yellow

S 1 TR, R


11.3.3. Configuration of time-overcurrent protection

The operating program REBWIN offers the following parametersfor setting time-overcurrent protection.


OCDT active Inactive

Pick-up value 0,1 20,0 2,0 0,1 IN

Delay 0 10000 2000 10 ms

Table 11.15 Parameters for setting time-overcurrent protection

All bay and current transformer details, are shown in theoverview.


11-23

Detail

Figure 11.10 Time-overcurrent protection

In the detail view, the time-overcurrent protection can beactivated per bay and the pick-up setting can be set.

ABB Power Automation Ltd REB500 1MRB520259-Uen / Mod. A

11-24

11.4. Circuit breaker pole discrepancy protection

11.4.1. Circuit breaker pole discrepancy protection function

The circuit breaker pole discrepancy protection is a local protectionfunction in the bay unit which supervises that the three circuit-breaker poles open and close simultaneously. The trippingcondition is fulfilled when at least one of the phase currents ishigher than setting and the difference between the phasecurrents (discrepancy factor) exceeds a given minimum for theset time.

M A X

&

PDF blocked

27405_PDF blocked

17205_Block PDF

37205_Block PDF

PDF timer

27305_PDF Trip

47305_PDF Trip

27105_PDF TRIP&

&

1

1

1

17710_Start PDF

PDF starting configured

I > PD _CPF *IFL1

I > PDF_CPF *IL2

I > PDF_CPF *IL3

MAX

MAX

MAX

I > PDF_CPLMAX

t 0

I

I , I , I )

MAX

L1 L2 L3

(greatest of

Figure 11.11 Block diagram of circuit breaker pole discrepancyprotection

To verify a pole discrepancy, the current criteria as well as thecondition of the circuit breaker auxiliary contacts, must be takeninto account (plausibility check). From the Figure 11.11: theoutput signal of the function is enabled by the binary input"17710_Start PDF".

If the input "17710_Start PDF" is not parameterised, then thisfunction is released.

The circuit-breaker pole discrepancy protection function does notintertrip the respective busbar zone.

Caution: Without a plausibility check, the opposing breaker canbe affected under certain conditions.


11-25

11.4.2. Available signals for circuit breaker pole discrepancyprotection




Record?

37205_Block PDF PDF slow no


Signalresponse


Trigger?Record?

17205_Block PDF fast yes

17710_Start PDF fast yes




Signaltype



Trigger?Record?

47305_PDF trip <Date / Time >PDF tripBay unit xRed

S 2 no

47405_PDF blocked PDF blocked *)Flashes yellow

S 2 no



11-26

Protectionfunction


Signaltype

Disturbancerec.:

Trigger ?Record?

27105_PDF TRIP PDF <Date / Time>PDF tripRed

S TR, R

27305_PDF trip PDF <Date / Time>PDF tripRed

S TR, R

27405_PDF blocked PDF PDF blockedFlashes yellow

S TR, R


11.4.3. Configuration of the circuit breaker pole discrepancyprotection

Circuit-breaker pole discrepancy protection settings:

Parameters Min. Max. Default Step Unit

PDF enabled Disabled

Setting 0.1 2.0 0.2 0.1 * IN

Delay 100 10000 1500 100 ms

Discrepancy factor 0.01 0.99 0.6 0.01 * Imax

Table 11.20 Setting parameters of the circuit breaker polediscrepancy protection

Where single-phase auto-reclosure is being applied on a line,the time delay of the circuit-breaker pole discrepancy protectionmust be set longer than the total auto-reclosure cycle time. Thediscrepancy factor is the maximum permissible differencebetween the amplitudes of two phases.

All bays are listed in the overview.


11-27

Detail

Figure 11.12 Circuit breaker pole discrepancy protection


11-28

11.5. Extended disturbance recorder

11.5.1. Function of the extended disturbance recorder

The disturbance recorder that is integrated in the busbarprotection can record bay unit currents, internal and externalbinary signals and optionally also voltages. The following optionsare available:

Analogue channels Recording timeChoice of sampling rate for

50Hz / 60Hz

Options 4 xcurrents

4 xvoltages

2400 Hz2880 Hz

1200 Hz1440 Hz

600 Hz720 Hz

Standard X 1,5 s 3 s 6 s

Option 1 X X 6 s 12 s 24 s

Option 2 X X 10 s 20 s 40 s

Table 11.21 Recording times of the disturbance recorder options

Providing only currents need to be recorded, the availablerecording time is doubled in the case of options 1 and 2.

The data for each bay unit and record can be saved to a file onthe PC in the standard ComTrade format. The data are thenavailable for viewing and evaluation using the ABB WinEveprogram

11.5.2. Available signals for the expanded disturbance recorder


Re-marks

Signalresponse

Disturbancerecorder:Trigger?Record?

36705_General start DR DR slow no



11-29

Signalresponse

Used fordisturbance rec.:Trigger? Record?

16705_Start DR_x16710…16750

fast yes



Protectionfunction


panel

Signaltype

Disturbance rec.:Trigger? Record?

26805_DR ready DR None S TR, R

26810_DR memory full DR None S TR, R

26815_DR recording DR None S TR, R

26820_DR record available DR None S TR, R



11-30

11.6. Release of the trip command

The effect of both the internal low voltage check as well as thegeneral release input signal per protection zone, on the differentprotection functions can be defined in a configuration matrix. Inthe matrix, the vertical columns are the release criteria and in thehorizontal rows are the affected functions.

Release criteriaFunctionality

Only

U< 1)

Only

ExternalReleaseInput 2)

U<AND

Externalrelease SS

3)

U<OR

ExternalreleaseSS 3)

Release ofthe related

bayfunction 4)

BBP_L1L2L3

BBP_L0

BFP

EFS

OCDT

PDS

ext. TRIP BBzone (CU)PJBZone (UC)

Ext. TRIP BBzone (BU)

Ext.TRIP

Table 11.25 REB500 release criteria

default values

1) can only be selected if “U<” is configured

2) can only be selected if input “31805_External release BB-zone” isconfigured

3) can only be selected if “U<” AND input “31805_External release BB-zone” is configured.

4) can only be selected if “U” AND/OR input “31805_External release BB-zone” is configured.


11-31

Figure 11.13 Low voltage check - overview

Figure 11.14 Low current check trip


11-32

Figure 11.15 Low voltage check - detailed view

11.6.1. Release of trip through internal undervoltage functionIn general, a short circuit on a busbar causes a voltage dip. Theundervoltage function senses this dip and can be used torelease the trip function according to Table 11.25.

The voltage dip caused by a fault must be lower than a certainalarm level. This level can be set with the use of the usersoftware (providing that the undervoltage check function hasbeen activated during the engineering phase).

The undervoltage check function operates per protection zone. Ifall voltages (phase-earth and/or phase-phase according to theconnection) are higher than the setting of the undervoltagecriteria, then the trip function of each bus zone and theirconnected circuit breaker will be blocked.

If a protection zone has not been allocated a voltage transformer(e.g. an open isolator), the undervoltage function of thisprotection zone will be released.

If the breaker back-up protection is started by the trip of anexternal distance protection, it can occur that the voltage dipcaused by a remote short circuit (line fault), does not reach theset undervoltage criteria. It is therefore normally recommendedthat the trip of the breaker back-up protection be madeindependent of the low voltage check function. Should thevoltage check function be selected in spite of the drawbacks,then the voltage dip setting must be verified by a networkcalculation.


11-33

The allocation of the voltage transformer within the busbar imageproceeds similar to the allocation of current transformers andcircuit breakers.

The position of the auxiliary contacts of the miniature circuitbreakers which protect the secondary circuit of the voltagetransformer, are not taken into account. If the miniature circuitbreaker is opened, the low voltage check function correspondingto the particular busbar zone is activated by REB500. If aprotection zone has been assigned multiple voltage transformers(undervoltage measurements), then all the low voltage releasesignals are wired in an “AND” configuration. This means that a“missing” voltage caused either by an open miniature circuitbreaker or an interruption of the transformer circuit does not leadto the release of the affected zone.

When an invalid voltage measurement is established (bay unit isswitched off / power failure), then the low voltage release of theaffected bay is activated so that the protection is not blocked.

11.6.1.1. Configuration - voltage transformer

This menu item appears only if voltage transformers have beenphysically built in.

Changes to the voltage transformer description as well as thevoltage transformer transformation ratio are shown in theoverview diagram:

Figure 11.16 Menu Configuration – voltage transformer


11-34

In the input field "Markings", the description can be expanded orchanged. The transformation ratio consists of nominal primaryand secondary ratio’s that can be entered into the input field"Transformer ratio". The connection configuration of the voltagetransformers is entered into the input field "Connection".

11.6.2. Release of trip with the aid of external enabling input"31805_External release BB-zone"

This input enables the tripping of individual busbars in accor-dance with Table 3.1 (see also Section 3.3.2.6).

Before this function is used at least one signal "31805_Externalrelease BB-Zone" must be configured.

If busbars are interconnected (e.g. closed longitudinal isolator),they are only released if the corresponding signals "31805_External release BB-Zone" are active and logically linkedtogether (logical AND ).

11.6.3. Overcurrent release of the trip command

The over current release is applicable for the tripping commandsof the busbar protection respectively intertripping commands(also applicable for end fault and breaker back-up protection). Ifthe measured feeder current value lies under the adjustablesetting level of the over current release function, then the trippingof the circuit breaker in the affected feeder will be prevented.

HEST 005016 C

I > 1

I >

I > 21110_Trip

I

I

I

BBP trip

L1

L2

L3

L1

L2

L3 &

BBP trip

BBP trip1

ITT

Figure 11.17 Diagram overcurrent release

If a trip results from the busbar protection and the pick-up settingof the over current release is not exceeded, then a tripping of theaffected feeder is prevented. However, the trip action concernedgenerates an event in the central unit and displays the result onthe local display unit of the CU (Local HMI). See also Section3.3.3 "Intertripping system".


11-35

The current pick-up setting can also be used for trip redirectionindependent of whether the overcurrent release function isconfigured or not.

Overview

Figure 11.18 Overcurrent release - overview

Detailed view

Figure 11.19 Overcurrent release - detailed view


11-36

11.7. Neutral current measurement

NOTE: Only in cases of impedance grounded networks will theneutral current monitoring be activated upon the client’s request.

The configuration of the busbar protection in impedancegrounded networks must take the following physical conditionsinto account:

• Limited single-phase to ground fault current levels (Ikmin 1phand k-factor values are possibly lower than the operatingrange of the phase measurement system).

• With single phase faults on the busbar, current flows awayfrom the busbar because of the relatively high short circuitimpedance (Ib, see also Figure 11.20 "Impedance groundednetwork"). The phase measurements of a stabilizing currentdirectional comparison protection system does not trip in thiscase.

In order to detect single phase faults in impedance groundednetworks and considering the comments already mentionedabove, an additional fourth measurement system (neutralmeasurement I0) is included in.

L1 L2 L3

Ik

I +Ik b

+Ib

|I +I -I |k b bk = |I +I + I |k b| | b

I = 2Ik b

k = 0,5

HEST 985008 C

Figure 11.20 Impedance grounded network


11-37

At a fault current Ik corresponding to twice the load current Ib,flowing in the affected phase L1, the restraining factor k is only0.5 (Figure 11.20). Thus the restrained amplitude comparisonfunction cannot detect the internal fault at the usual k setting of0.80. Furthermore, the current is flowing away from the busbarso the phase comparison measures a phase-angle ofapproximately 180 degrees thus preventing the trip command.Therefore the neutral current I0 has to be measured as well andevaluated together with the restrained amplitude comparison andthe phase comparison functions.

The neutral current evaluation is only necessary by phase-to-ground faults and should only be used for these faults. Themonitoring of the conductor currents serves as the measuringcriteria. Whether it is included in the evaluation or not dependson the levels of the phase currents. Even if the phase currentsdo not drive the c.t’s into saturation, their ratio errors can stillproduce an apparent neutral current on the secondary side. Theneutral current is therefore only evaluated when none of thephase currents exceeds a set value (typically 5 IN). This preventsthe neutral current from being evaluated for phase-to-phase andthree-phase faults.

Finally, the harmonic level is monitored as added security thatthe neutral current can only be evaluated when there is definitelyno influence due to c.t. saturation. This feature also prevents theevaluation of the neutral current during transformer inrushcurrents.

Caution: To ensure in all cases a problem free blocking of theneutral current monitoring function during current transformersaturation the inductive load on the current transformer must bereduced as much as possible. This means that under nocircumstances are electromechanical relays or similar devicesallowed in the current transformer circuit.

For exact dimensioning or setting of the neutral current meas-urement systems, detailed site data are absolutely essential.

Per busbar section:

• IKS3max max. phase fault current for 3-phase short circuit

• TS3max time constant of the direct current component of lS3max

• IKS3min max. phase fault current for 3-phase short circuit


11-38

• TS3min time constant of the direct current component of IKS3min


• TS1max time constant of the direct current component ofIKS1max

• IKS1min max. phase fault current for 1-phase short circuit


Per feeder:

• IKA1max max. phase fault current for single phase short circuit

• TA1max time constant of the direct current component ofIKA1max

• IBAmax max. load current

• INprim current transformer primary rated current

• INsec current transformer secondary rated current

• PN current transformer rated power

• n overcurrent factor of the current transformer

• UK knee-point voltage of the current transformer

• PE current transformer losses

• RCT resistance of the secondary winding

• l length of the current transformer secondary wiring(single length)

• A square area of the current transformer wiring

• PBG sum of the burden of all connected devices

• RBG sum of the burden resistors of all connected devices

The following points must be checked:

• Stability of the l0 measuring system for external faults

• Smallest allowed base current (trigger level) for thedifferential current comparison

• Saturation point of the transformer relevant to the necessaryoperating range of the neutral current measurement (thetransformer should not saturate in the operating range of thel0 measurement).


11-39

11.7.1. Function of neutral current measurement

Neutral measurement is used chiefly in resistance earthed net-works. The resistor (or resistors) very often limits the single-phase phase fault current to a value which lies below theoperating range of the phase measurement system. Also, in thecase of single phase faults on the busbars, currents flow awayfrom the busbars because of the relatively high short circuitimpedance. The phase measurement of a current stabilizingdirectional comparison protection does not trip in this case.

A fourth measuring system namely, neutral measurement, isused to detect single phase faults in resistance earthed net-works. The best technical solution for detecting neutral currentsis with the use of core-balance current transformers that en-compass all three phases. If these are not available, then theneutral current is determined by the sum of the three phasecurrents. This is known as the Holmgreen-circuit.

In this case, the main current transformers, power system timeconstant, the short circuit currents as well as the "Inrush"currents of the transformers, must be checked with regard to therequirements of the neutral measurement of the REB500.

11.7.2. Configuration of neutral current measurement

The following data are required for the interpretation of theneutral current measurement:

Necessary data required

Per busbar section:



• IKS3min min. phase fault current for 3-phase short circuit


• IKS1max max. phase fault current for single phase short circuit


• IKS1min min. phase fault current for single phase short circuit

• TS1min time constant of the direct current component ofIKS1min


11-40

Per feeder:

• IKA1max max. phase fault current for single phase short circuit

• TA1max time constant of the direct current component ofIKA1max

• IBAmax max. load current

• INprim current transformer primary rated current

• INsec current transformer secondary rated current

• PN current transformer rated power

• n overcurrent factor of the current transformer

• UK knee-point voltage of the current transformer

• PE current transformer losses

• RCT resistance of the secondary winding

• l length of the current transformer secondary wiring(single length).

• A square area of the current transformer secondarywiring

• PBG sum of the burden of all connected devices

• RBG sum of the burden resistors of all connected devices

11.7.3. Calculations and verification

For every feeder the following calculations and checks must becarried out:

11.7.3.1. Calculating the total burden PB

2secNI2

A56l

BGPBP ⋅⋅⋅

+=

or when RBG is given

2secNI2

A56l

BGRBP ⋅⋅⋅

+=

11.7.3.2. Calculating the actual overcurrent factor n'

EPBPEPNP

nn'++

⋅=

If RCT is given instead of PE


11-41

2secNCTE IRP ⋅=

If UK is given instead of n

EN

secNKPP

IUn+⋅=

11.7.3.3. Checking the stability in the case of an external fault

For every feeder, the following 3 conditions must be fulfilled:

1.Nprim

KI5

In⋅

≥′ 1Smax

2.Nprim

KI5

In⋅

≥′ 1Smax

3. n’ ≥ 10 for TS3 ≤ 80ms

n’ ≥ 40 for 80ms < TS3 ≤ 120ms

n’ ≥ 100 for 120ms < TS3 ≤ 300ms

TS3 the greater value of TS3max and TS3min

11.7.3.4. Calculating the setting of IKmin

Ikmin ≥ 0.7 · IBmax

IBmax is the highest load current of all feeders. To ensure that nospurious tripping occurs in the case of current transformer circuitfaults, a setting of 1.2 · Ibmax is recommended.

11.7.3.5. Checking the trip action in the case of busbar short circuit(ground fault)

To ensure that the trip action, in the case of a busbar shortcircuit, is not blocked by a harmonic blocking condition, thefollowing conditions must be fulfilled for each feeder:

−⋅⋅≥−

max1AT025.0

max1A e1NprimI

AIT710n'

IA = the greater value of IKB and 5 x INprim

IKB = the vector sum of IKA1max and IBAmax


11-42

11.7.3.6. Example

Rated voltage UN: 50 kV

Data per busbar section (both sections have the same values)

IKS3max kA 13.8

TS3max ms 32

IKS3min kA 7

TS3min ms 32

IKS1max kA 4.9

TS1max ms -

IKS1min kA 1.8

TS1min ms -

Data per feeder

Feeder 01 02 03 05 06 07

IkA1max kA 4.9 0 0 4.9 0 0

TA1max ms - -

IBAmax A 600 230 120 600 170 120

INprim / Insec 600/1 300/1 150/1 600/1 300/1 150/1

PN VA 25 25 15 25 25 15

n 20 20 20 20 20 20

PE VA 2.45 1.75 0.96 2.45 1.75 0.96

PB VA 0.3 0.3 0.2 0.3 0.3 0.2

No details are given about direct current time constants in thecase of single-phase faults, therefore the maximum values havebeen roughly estimated.

Assumption: Feeders 01 and 05 supply IKS1max to the busbars

Positive sequence impedance RL101 of line 01: 1,59 Ω

Positive sequence impedance RL105 of line 05: 1,08 Ω

The sum of the resistances in parallel is = 0.644 ΩΩΩΩ


11-43

H..I

ULKS

N 05110314813

503 min1

=⋅⋅

=ω⋅⋅

≈

s...

RL

RLT

ES 07930

644005110

min1 =≈≈=

Calculation of n'

Feeder 01 02 03 05 06 07

PN 25 25 15 25 25 15

n 20 20 20 20 20 20

PE 2.45 1.75 0.96 2.45 1.75 0.96

PB 0.3 0.3 0.2 0.3 0.3 0.2

EPBPEPNPnn'

+

+⋅=

199 260 275 199 260 275

Checking the stability in the presence of an external fault

Feeder 01 02 03 05 06 07

Inprim 600 300 150 600 300 150

n 199 260 275 199 260 275

IK1Smax 4'900 4'900 4'900 4'900 4'900 4'900

Nprim

K

II⋅5

1Smax 1.64 3.27 6.54 1.64 3.27 6.54

Nprim

K

IIn⋅

≥′5

1Smax o.k. o.k. o.k. o.k. o.k. o.k.

IK3Smax 13'800 13'800 13'800 13'800 13'800 13'800

Nprim

K

II⋅53Smax 4.6 9.2 18.4 4.6 9.2 18.4

Nprim

K

IIn⋅

≥′5

3Smax o.k. o.k. o.k. o.k. o.k. o.k.

TS3 32 32 32 32 32 32

n' ≥ 10 o.k. o.k. o.k. o.k. o.k. o.k.

Calculating the setting of IKmin

Feeder t 01 02 03 05 06 07

IBAmax 600 230 120 600 170 120


11-44

Thus follows: IBmax = 600 A

Lowest possible setting: IKmin = 0.7 · 600 = 420 A

Recommended setting: IKmin = 1.2 · 600 = 720 A

Tripping of the busbars - short circuit

Feeder 01 02 03 05 06 07

Inprim 600 300 150 600 300 150

n’ 199 260 275 199 260 275

IBAmax 600 230 120 600 230 120

IKA1max 4.9 0 0 4.9 0 0

TA1max 0.0793 0.0793

KB 5500 5500

IA 3'000 3'000

−⋅⋅

−max1

0250

max1 1710 AT.

A eNprimIAIT

76.2 76.2

−⋅⋅≥

−max1

0250

max1 1710 AT.

A eNprimIAITn'

o.k. o.k.


11-45

11.8. Interbay bus (IBB) connection

11.8.1. Introduction

An interface is optionally available for connecting the numericalbusbar protection to a station control system or stationmonitoring system (SCS/SMS).

NetworkControl

Bay

Units

E

C

Bay

Units

Bay

Units

E

C

Bay

Units

E

C

Bay

Units

E

C

Bay

Units

E

C

E

C

NetworkControl

LONIEC-60870-5-103

SCS/SMS

REBWIN

Modem

3)

2)

1)

RE.316RE.58.

Figure 11.21 Overview of REB500 interfaces

Figure 11.21 Overview of REB500 interfaces shows the commu-nication interfaces provided on REB500:

1. REBWIN connected to the HMI interface at the front of thecentral unit or a bay unit for commissioning, maintenanceetc., of the REB500 system.

2. REBWIN permanently connected via a modem or opticalfibre cable to the interface at the back of the central unit(remote HMI)

3. Interbay bus interface.


11-46

In contrast to feeder control and protection bay units, REB500 isequipped with only a single interbay bus interface via which allthe REB500 bay units in the entire station communicate. Thishas to be taken into account by the various bus protocols.

11.8.2. Hardware

11.8.2.1. Basic components

REB500 can support a maximum of two IBB interfaces at thesame time and these are configured in the database whileengineering the protection scheme. Suitable communicationprotocols are LON and IEC 60870-5-103. The simultaneous useof two LON or two IEC-103 interfaces is not possible.

Physically, the interface is two extra modules 500CIM01 or500CIM04 and 500TRM03 which, depending on the backplanein use, are inserted into the following slots in the central unit:

Backplane 500CUB01: CIM module in SLOT 15 and500TRM03 in SLOT 16

Backplane 500CUB02: CIM module in SLOT 13 and500TRM03 in SLOT 14

500CIM01/04

To enable REB500 to communicate via an interbay bus, aprocessor module 500CIM01 or 500CIM04 (basic processormodule 500CPU02 or 500CPU04) and a connector module500TRM03 have to be fitted in the central unit. In the case of aLON bus, a sub-module 500LBI01 (or 500LBI02) is also pluggedonto the 500CIM01/04 module (see Section 11.8.2.2 Hardware).


11-47

A

B

C

D

Figure 11.22 500CPU02 / 500CPU04

500TRM03

Function: Optical interface for communication with thestation control system. The 500TRM03 is anelectrical-to-optical signal converter.

Settings: Rotary configuration switch.

0: Either no configuration or configuration by thesoftware.

1: The serial module in socket A on the500CIM01/04 is connected to the opticalsend/receive interface 2,The IP-LON module insocket B on the 500CIM01/04 is connected tothe optical send/receive interface 1, LON

2: Standard REB500 configuration.

The serial channel on the frontplate of the500TRM03 is connected to optical channel 2, →IEC103. The IP-LON module in socket B on the500CIM01/04 is connected to the opticalsend/receive interface 1, → LON.

3-15: spares

LON cable: A ribbon cable is supplied that is inserted intosocket B on the 500CIM01/04 and socket B onthe 500TRM03.


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IEC-103 cable: An RS-232 cable (25 pin Sub-D plug to 9 pinSub-D plug) is supplied that is inserted into"Serial port 2" on the 500CIM01/04 and thesocket marked "SER" on the 500TRM03.

B

AC

D

Serial Sub-D Optical 2 Optical 1 Rotary switch

Figure 11.23 500TRM03

11.8.2.2. LON hardware configuration

Where LON is being used as the IBB protocol, the followinghardware has to be installed in the central unit:

1 x CIM module (500CPU02 or 500CPU04)

1 x LON BUS interface (500LBI01 = TEWS TIP813-10,500LBI02)

1 x ribbon cable

1 x 500TRM 03

Remove all the jumpers on the 500LBI01.

Connect up the ancillary hardware as shown in Figure 11.24"Ancillary hardware needed for a LON IBB" and then install it inthe central unit, taking care that the 500LBI01(or 500LBI02) isinserted into SOCKET B on the CIM module and the ribboncable connects the 500TRM03 also to SOCKET B on the CIMmodule.


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LON BUS optical Tx and Rx

LON bus interface

Ribbon cable

500TRM03CIM module

SOCKET B

Service pin

Figure 11.24 Ancillary hardware needed for a LON IBB

Use an optical fibre cable with a core diameter of 62.5 µm and aconnector Type BFOC/2,5 for the connection between the opticalLON bus interface on the 500TRM03 and the star-coupler orSCS. The cable cores have to be transposed when inter-connecting two devices (i.e. the optical LON output Tx on the500TRM03 must go to the optical input Rx on the star-coupler orSCS and the optical LON input Rx on the 500TRM03 must comefrom the optical output Tx on the star-coupler or SCS).

11.8.2.3. IEC 60870-5-103 hardware configuration

1 x CIM module (500CPU02 or 500CPU04)

1 x 500TRM03

1 x IEC-103 connecting cable

An RS-232 serial cable (25 pin Sub-D plug to 9 pin Sub-D plug)is supplied for connecting the 500CIM01/04 and the 500TRM03.It is inserted into “Serial port 2” on the 500CIM01/04 and the


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socket marked “SER” on the 500TRM03 as shown in Figure11.25. A standard optical fibre interface with a Type BFOC/2,5connector is provided. The corresponding connector is “Opt. 2”located on the 500TRM03 in the central unit.

A data transfer rate of either 9600 Bit/s or 19,200 Bit/s can bechosen.

Figure 11.25 Ancillary hardware needed for IEC-60870-5-103

11.8.3. Common IBB functions

11.8.3.1. Basic IBB configuration

The dialogue for configuring the communication is accessed byselecting the menu item “Communication” in the “Settings” menuof the user program REBWIN.


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Figure 11.26 Dialogue for configuring the communication

The parameters must be defined before configuration of thecomplete communications system is started.

The field “Sync source” defines which protocol is used tosynchronise the REB500 from an external source.

LON:

Setting Significance Defaultsetting

Clock address: Predefined LON network variable.Does not normally have to be changed.

1023

Clock warningaddress:

Predefined LON network variable.Does not normally have to be changed.

1022

Bus line: Number of the LON IBB (where several exist) 0..2. 1

Node address: Distinguishes between REB500’s, if several areconnected to the same LON segment. The nodeaddress can be, but does not have to be identical tothe LON node address 0..63.

1

Sync source: When this is active, the REB500 time issynchronised via the LON bus (clock address, clockwarning address)

active

Table 11.26 LON configuration


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IEC-103:

Setting Significance Defaultsetting

Address: IEC-103 station address (on link layer) 1..254 1

Baud rate: Data transfer rate 9600 or 19200 Baud 9600

Table 11.27 IEC-103 configuration

11.8.3.2. REB500 event configuration

For changes in status generated by REB500 to be transferred asevents to an SCS/SMS, the corresponding signals must beconfigured as events using the dialogue that opens afterselecting the REBWIN menus “Configuration / Binary module /Configuration of events” (see Figure 11.27). To which IBB anevent is sent is determined by selecting the appropriatecheckbox IBB 1 or IBB 2 when configuring the signal.

Figure 11.27 Configuring signals as events

Diagnostic and system events are always available for transferwhichever protocol is in use and cannot be configured.

If both IBB 1 and IBB 2 are used, an event can be assigned toboth interfaces.


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11.8.3.3. Transfer of differential current values

General descriptionTo keep the load on the IBB as low as possible, the bus zonedifferential currents are checked cyclically, but only actuallytransferred via the bus if the value has changed.

Example:

Diff.current

Values trans-ferred to the SCS

0 - - 100 - - - 200

Zero limit

Figure 11.28 Transmitted values and the zero limit

To stabilise the display during normal operation, differentialcurrents below the zero limit (dead band) count as zero and aretransferred as such.

Providing the condition for transmitting a current value is fulfilled,all the differential currents belonging to the respective zone aresent to the SCS/SMS.

Detailed description of the delta/dead band algorithm

Conditions to be fulfilled for transmitting differential currents asevents to the SCS:

Transmit conditions:diff = diff + | new current value - old current value |if | diff | > delta

thendiff = 0

if | new current value | < dead bandthen

old current value = 0, send 0else

old current value = new current value, send new currentvalue


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Delta value: Delta defines how big the integral of thechanges in the value of the measurement(see condition below) has to be for a newvalue to be transferred via the bus.

Dead band value: The dead band on the other hand issimply the threshold below which a valuecounts as zero.

Differential current measurements are configured in the REB500database and cannot be changed using either REBWIN orREBCON. The significance of the differential current parametersis as follows:

Update period: - Determines how often thedifferential current measurementhas to be updated.

- Applies to all bus zones.

Delta value L1_L2_L3: - Delta per bus zone for phasesL1, L2 and L3.

Dead band value L1_L2_L3: - Dead band per bus zone forphases L1, L2 and L3.

Delta value L0: - Delta per bus zone for theneutral current L0.

Dead band value L0: - Dead Band per bus zone forthe neutral current L0.

Enable diff. currents: - Enables polling of the bus zonedifferential currents.

The tables below show the interrelationships, units, defaultsettings and the ranges and setting intervals (steps) of theparameters:

Parameter Bus zone 1..n

Update Period (sec.) Default: 60

Range: 0 - 1000

Step: 1

Table 11.28


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Parameter Bus zone 1 Bus zone 2 Bus zone n

Enable diff. currents(yes/no)

Default: Yes Yes No

Delta value L1_L2_L3 (A) Default: 10

Range: 0 - 65535

Step: 1

Default: 10

Range: 0 - 65535

Step: 1

Default: 10

Range: 0 - 65535

Step: 1

Dead band valueL1_L2_L3 (A)

Default: 5

Range: 0 - 65535

Step: 1

Default: 5

Range: 0 - 65535

Step: 1

Default: 5

Range: 0 - 65535

Step: 1

Delta value L0 (A) Default: 10

Range: 0 - 65535

Step: 1

Default: 10

Range: 0 -65535

Step: 1

Default: 10

Range: 0 - 65535

Step: 1

Dead band value L0 (A) Default: 5

Range: 0 - 65535

Step: 1

Default: 5

Range: 0 - 65535

Step: 1

Default: 5

Range: 0 - 65535

Step: 1

Table 11.29

Note: Only those neutral currents L0 of the various bus zonesare transferred to the SCS that were correspondingly configuredat the time the scheme was engineered.

Caution: ‘Delta’ and ‘Dead band’ settings that are too low resultin a high data load on the bus. For this reason, care should betaken to set reasonable values.

11.8.4. LON

11.8.4.1. Installing a LON node

When a LON bus interface is put into operation for the first time,it is not configured and so the first task is to do so using the LONnetwork manager’s program.

A suitable LON network manager’s program is the “LON NetworkTool”.

The service telegram to permit configuration to be carried out istransmitted by the LON bus interface (500LBI01) when thebutton marked “LON” on the 500TRM03 is pressed (see Figure11.23).


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11.8.4.2. Addressing

The identification of the REB500 events and the mapping to thecorresponding process objects in the SCS database is done onthe basis of the station address (2 Byte, also referred to as unitaddress) and the object address (2 Byte), both of which areincluded with every event telegram.

Station address (unit address)

In most cases, there will only be one REB500 per substation andtherefore only one IBB connection (to the central unit).

The 2 Byte station address (unit address) is composed asfollows:

HighByte = Physical bus line on the REB500 0 ¦ 1 ¦ 2

LowByte = Node address 0…63 . This address must beunique on the particular IBB as it is used toconstruct the station address (unit address). Itmay be the LON node, but does not have to be.Where several REB500’s are connected to anSCS, this address also distinguishes betweenthem.

The address can be entered using REBCON, the engineeringtool (see Section 11.8.3.1).

Object address

The object address defines a REB500 event, measurement orcommand. It is composed as follows:

Events:

HighByte = 32 x Node_Id + Device_Id ≡ REB500 HW unit

(e.g. BU23, BIO in Slot 4)

LowByte = Event_Config_Id

where: Event_Config_Id = event number

Measurements (differential currents):


LowByte = ((Buszone_Id– 1) * 4) + Phase_Id


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where: Device_Id = Device_Id of CMP (generally 1)

Node_Id = Node_Id of CMP (generally 1)

Buszone_Id = bus zone number

Phase_Id = 1 for L1

2 for L2

3 for L3

4 for L0

Commands:


LowByte = 128 + Command_Id (command number)

where: Device_Id = Device_Id of CMP (generally 1)

Node_Id = Node_Id of CMP (generally 1)

Command_Id = command number, e.g. 1 for resetting LED’s and latchedrelays

Caution: Every time the configuration is changed, the eventnumbers are regenerated (consecutive numbers). All the eventnumbers can thus change if the event configuration is changed.

11.8.4.3. Configuration

Configuring the LON IBB protocol and time synchronisation

Refer to Section 11.8.3.1 for the basic configuration. The stationaddress (unit address) is determined by selecting the bus lineand the node address (see Section 11.8.4.2).

Activating the Sync. Source checkbox (only for a LON IBB)means that the REB500 time is synchronised via the LON IBB.Be sure that only one IBB is being used for synchronisation.

Time is synchronised via the LON IBB with the aid of twopredefined LON network variables (Clock and Clock warning)having a fixed selector. The selector identifies the function of thenetwork variable (time synchronisation in this case). REB500recognises 1024 network variables that are stored in a table with1024 entries (0…1023).


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The table includes the selectors and other settings determiningthe functions of the network variables (input or output, servicetype, address table index etc.). The default setting for timesynchronisation via the LON IBB is determined by the entries forthe network variables 1022 and 1023, i.e. for this mode ofsynchronisation, it is only necessary to refer to these entries inthe Communication menu (Clock addr.: 1023 and Clockwarning addr.: 1022). Should some other entry (other networkvariable) be used for time synchronisation, a LON networkmanagement program (e.g. “LON Network Tools”) has to beused first to reconfigure the network variables for timesynchronisation via the LON IBB (selector, input etc.) and thenthe number of the network variable (table entry) has to beentered in the Communication menu (Clock addr.:, Clockwarning addr.:). This procedure is not recommended for thisreason.

Configuring events for the LON IBB

REB500 generates the following types of events for transfer viathe LON IBB (see Section 11.8.3.2):

1 Signal events (single-point indication).

Format: DMCD type 129 → Single-point informationwithout time tag [LAG 1.4]

DMCD type 130 → Single-point information withtime tag [LAG 1.4]

2 Isolator and circuit-breaker position events (double-pointindication)

Format: DMCD type 131 → Double-point informationwithout time tag [LAG 1.4]

DMCD type 132 → Double-point informationwith time tag [LAG 1.4]

3 Diagnostic events and system events

Format: DMCD type 139 → Pulse counter value withtime tag [LAG 1.4]

The LON protocol supports five event filters that can beaddressed by the SCS while communication is being initiatedwith it (see SCS manual). The various filters serve the followingpurposes:


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Filter 0: Enables all events that were configured for the LONIBB including diagnostic events.



Filter 3: Enables all events that were configured for the LONIBB excluding diagnostic events.

Filter 4: Enables all events that were configured for the LONIBB excluding diagnostic events.

Configuring measurements (differential currents) for theLON IBB

REB500 makes four differential currents (L0, L1, L2, L3) per buszone available for transmission via the LON IBB (see Section11.8.3.3):

Format: DMCD type 137 → Short measured value withfloating point but withouttime tag

DMCD type 138 → Short measured value withfloating point but withouttime tag

The object addresses for the various differential currents aredetermined using the relationship given in Section 11.8.4.2.

11.8.4.4. Commands via the LON IBB

REB500 makes a command available for resetting latchedrelays. The same command resets the tripping LED’s on thefrontplate display. The definition of the command is as follows:

Double command DMCD type 46 where S_E = 0 or 3 andSCS = 2 (command qualifier)

The command number (Command_Id) for determining the objectaddress (see Section 11.8.4.2) is ‘1’.

11.8.4.5. Displaying status information (events)

Diagnostic information

Internal system diagnostic signals are transferred as pulse-counter type signals (32 Bit = 4 Byte).


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Format: DMCD type 139 → Pulse counter value withtime tag

The significance of the BCR Bytes are as follows:

Byte number Significance

Byte 3 (HB) Always 0

Byte 2 Init = 1

Major error = 2

Minor error = 4

Not ready = 8

Ready = 16

Last wish = 32

Shutdown = 64

No status =1 28

Byte 1 Class 0..40 , defines the SW subsystem

Byte 0 (LB) Error number 0..255

Table 11.30 BRC Bytes

Class:

0 = BBP 16 = BFP

1 = ITT 17 = DRR

2 = BCF 18 = MPL

3 = DIA 19 = EFP

4 = TGR 20 = PDF

5 = EMI 21 = BOC 6 = LMI 22 = BPP 7 = DAC 23 = DIE 8 = TIM 24 = DRD 9 = DBS 25 = EVA10 = SIG 26 = GPI11 = EVR 27 = LAC12 = RFS 28 = IAC13 = SPR 29 = CMD14 = MBA 30 = LPL15 = OCP 31 = TRC


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Status information

Events for the SCS are configured using either REBWIN orREBCON. Every time the configuration is changed, the eventnumbers are regenerated (consecutive numbers). All the eventnumbers can thus change if the event configuration is changed.

This task is performed by an ACCESS application to preventhaving to recalculate the station (unit) and object addressesmanually every time the events are reconfigured or changed.

The data input for the ACCESS application is the REBWIN orREBCON database file <filename>.mdb and the REB500system database attribut.sdb. The ACCESS applicationdetermines the new addresses using the algorithms. The outputgenerated by the ACCESS application is a text file (export file)with the default extension <filename>.exp which contains allthe information necessary.

The file has the following structure:

• Lines 1 and 2 = Station, DB versions etc.

• Line 3 = Column header

• Line 4 onwards = Data

The columns are separated by a semicolon “;”.

The LON station (unit) address is in column 11and the LONobject address in column 12 of the text file (export file).

The export file is created during the engineering process.

The following three pages show an example of an export filefrom the ACCESS application, Table 11.31.


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Lines 1 and 2

Module Type ofIBB

StationAddr.

REBWINVersion

REBCONVersion

DBVersion

DB Date Export Date Export Tool Version

REB500 LON 257 4.10 4.10 V0.00AR 1998-11-10 98-12-17 AI 98-12-11 V2.10

StationName

Bay Name DeviceName

4.Field

5.Field

SignalName

Technical SignalIdentifier

Event Text Signal Text Signal Type Unit ObjectAddress

LON NVIndex

LON NVBitNumber

LONBay-Bay

EventFilterNr.

FunctionNr.

REB GI

Testanlagemit 2 Seg.4 BU

BBP257 A1 EVENT BU 1 5 500BIO01 11210_Block.Ausgangsrelais

11210_Block.Ausgangsrelais

SinglePointIndicationType 0

9239 FALSE 15 1 FALSE


BBP257 A1 EVENT BU 1 5 500BIO01 11610_Ext.Rückstellung

11610_Ext.Rückstellung

SinglePointIndicationType 2

9253 FALSE 15 1 TRUE


BBP257 A1 EVENT BU 1 5 500BIO01 11620_Revision_1-Ein 11620_Revision_1-Ein SinglePointIndicationType 2



BBP257 A3 EVENT BU 3 5 500BIO01 15210_Blockierung UMZ 15210_Blockierung UMZ SinglePointIndicationType 2



BBP257 A3 EVENT BU 3 5 500BIO01 17205_Blockierung SPD 17205_Blockierung SPD SinglePointIndicationType 2



BBP257 CU EVENT CU Rack1 20500BIO01

42315_SSS Auslösung L1 42315_SSS Auslösung L1 SinglePointIndicationType 2











11-64

StationName

Bay Name DeviceName

4.Field

5.Field

SignalName



LON NVIndex

LON NVBitNumber

LONBay-Bay

EventFilterNr.

FunctionNr.

REB GI



43305_SVS Auslösung t1 43305_SVS Auslösung t1 SinglePointIndicationType 2



BBP257 A1 EVENT BU 1 7 500AIP01 AIP(7) AIP(7) SystemDiagnosisMonitoring(PC)



BBP257 CU EVENT CU Rack1 7500CPU02

CSP(7) CSP(7) SystemDiagnosisMonitoring(PC)



BBP257 A2 EVENT BU 2 5 500BIO01 BIO(5) BIO(5) SystemDiagnosisMonitoring(PC)


















BBP257 CU EVENT CU Rack1 11500CPU02

CIM(11) CIM(11) SystemDiagnosisMonitoring(PC)



BBP257 CU MV_DIFFI1

- BZ1.L1 BZ1.L1 MeasurementFloatingPoint

A 8449 FALSE 15 2 TRUE


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StationName

Bay Name DeviceName

4.Field

5.Field

SignalName



LON NVIndex

LON NVBitNumber

LONBay-Bay

EventFilterNr.

FunctionNr.

REB GI


BBP257 CU MV_DIFFI2




BBP257 CU MV_DIFFI3




BBP257 CU MV_DIFFI0




BBP257 CU MV_DIFFI1




BBP257 CU MV_DIFFI2




BBP257 CU MV_DIFFI3




BBP257 CU MV_DIFFI0




BBP257 CU CMD_RESET

- CommandType 0


Table 11.31 Example of an ACCESS application export file


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11.8.5. IEC 60870-5-103

11.8.5.1. Introduction

Busbar protection is not one of the types of protection defined inIEC 60870-5-103. Nevertheless, the commands and signals ofthe REB500 system are modelled as far as possible on functionsdefined in the IEC recommendation. The functional scope of thestation protocol is therefore reduced. The backup protectionfunctions breaker failure, time-overcurrent and end fault that areoptionally available with REB500 are also supported.

According to the IEC recommendation, usage of the privaterange is only permitted regarding the compatibility of existingdevices. For this reason, additional REB500 functions that arenot defined in the recommendation were implemented accordingto the future-oriented generic part of IEC 60870-5-103.

Refer to IEC 60870-5-103 for an explanation of the variousabbreviations.

11.8.5.2. General functions

The tables below define the functional scope of REB500according IEC 60870-5-103. The details are to be found in therecommendation itself.

System functions in monitoring direction

INF Description GI TYPE COT

<0> End of general interrogation (polling) – 8 10

<0> Time synchronisation – 6 8

<2> Reset frame control bit (FCB) – 5 3

<3> Reset CU – 5 4

<4> Start/restart – 5 5

<5> Power on – 5 6

Table 11.32 System functions in monitoring direction

Notes: The information number 0 refers to the global functiontype and is the same for all system functions. The information numbers 2 to 5 are used with FUN in relation tothe main function of a protection system.


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Status signals in monitoring direction

INF Description GI TYPE COT REB500 signal configuration

<18> Protection active x 1 1,9 41810_In service (CU output)21805_In service (BU output)

<19> LED reset – 1 11 31810_ext_reset (CU input)11610_ext_reset (BU input)

<20> Blocks the supervisoryequipment

x 1 9,11 31215_Block.IEC Master_Direction(CU input)

Table 11.33 Status signals in monitoring direction

Supervisory signals in monitoring direction


<47> General alarm x 1 1,9 41805_Alarm (CU output)

Table 11.34 Supervisory signals in monitoring direction

Disturbance signals in monitoring direction


<68> General trip – 2 1 42305_BBP trip (CU output)21110_TRIP (BU output)21305_Trip (BU output)

<69> Trip L1 – 2 1 42315_BBP trip_L1 (CU output)23315_BFP trip_L1 (BU output)



<85> Breaker failure – 2 1 43305_BFP trip_t1 (CU output)43310_BFP trip_t2 (CU output)23305_BFP trip_t1 (BU output)23310_BFP trip_t2 (BU output)

<90> Trip I> – 2 1 45305_OCDT trip (CU output)25105_OCDT TRIP (BU output)25305_OCDT trip (BU output)

<92> Trip IN> – 2 1 42310_BBP_trip_L0 (CU output)

Table 11.35 Disturbance signals in monitoring direction


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Generic functions in monitoring direction

INF Description GI TYPE COT

<240> Read headings of alldefined groups

– 10 42,43

<241> Read values or attributes ofall entries of one group

– 10 42,43

<242> Not used – – –

<243> Read the directory of asingle entry

– 11 42,43

<244> Read the value or attributeof a single entry

(x) 10 1,2,9,11,12,42,43

Table 11.36 Generic functions in monitoring direction

Generic functions in control direction

INF Beschreibung TYPE COT

<240> Read headings of all defined groups 21 42

<241> Read values or attributes of all entries of onegroup

21 42

<242> Not used – –

<243> Read the directory of a single entry 21 42

<244> Read the value or attribute of a single entry 21 42

Table 11.37 Generic functions in control direction

Commands in control direction

INF Description TYPE COT

<19> LED reset 20 20

Table 11.38 Commands in control direction


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11.8.5.3. Disturbance recorder

Disturbance data are uploaded and displayed in accordance withthe IEC recommendation with the following exceptions:

a) REB500 supports a maximum of 15 records per bay unit, butonly the first (oldest) eight in the queue can be displayed inaccordance with the recommendation.

b) Of the records that are displayed, only the oldest can bedeleted or uploaded. This is determined by the REB500principle.

c) The time stamp invalid Bit (IV) in a disturbance record isalways set, because the CIM module is unaware of thesynchronisation status at the instant of the record.

11.8.5.4. Generic REB500 functions

Displaying status information (events)

Diagnostic information

Status and diagnostic information is generated by the variousREB500 application software modules and transferredspontaneously as events every time the status changes. Aseparate group exists for diagnostic information with an entry forevery subsystem of the REB500 system software REBSYS.


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Diagnostic event group

ENTRY No. Group 64 (0x40)

0 (Heading) Diagnostic information1 BPP (Busbar protection)2 ITT (Intertripping)3 BCF (Binary input and output configuration facility)4 DIA (Diagnostic)5 TGR (Test generator)6 EMI (External man/machine interface)7 LMI (Local man/machine interface)8 DAC (Data access)9 TIM (Time management)10 DBS (Database system)11 SIG (Signal processor)12 EVR (Event recording)13 RFS (Remote file system)14 SPR (Signal pre-processing and recording)15 MBA (Multi-function bus administrator)16 OCP (Overcurrent protection)17 BFP (Breaker failure protection)18 DRR (Disturbance recorder)19 MPL (Multi functional process bus library)20 EFP (End-fault protection)21 PDF (Pole discrepancy function)22 BOC (Binary input/output control)23 BPP (Binary pre-processing)24 DIE (Diagnostic extensions)25 DRD (Disturbance recorder dispatcher)26 EVA (Event and alarm handling)27 GPI (General purpose interface)28 LAC (LON application converter)29 IAC (IAC application converter)30 CMD (Command processor)31 LPL (LON protocol layer)32 TRC (Traceability)

Table 11.39 Diagnostic event

The ASDU 10 ‘Generic data’ is used with the following attributes:

CAUSE OF TRANSMISSION 1 Spontaneous

COMMON ADDRESS OF ASDU 0 / 1..59 REB500 CU / REB500 BU

FUNCTION TYPE 254 GENeric function type


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With the exception of the header (entry 0), the current values ofthe entries are not available on request. The response to thecorresponding generic read command is therefore COT 43‘invalid data response to generic read command’.

The current value of the group header (entry 0) corresponds tothe number of subsystems in the REB500 system software.

COD Data type Length Number Value / Significance

<10> Description <1> OS8ASCII 21 1 “Diagnostic information”

<1> Current value <3> UI 1 1 Number of SW subsystems

Table 11.40 Directory entry for GIN 0x4000 (header)

All the other entries in this group consist of the followingattributes that are needed to describe a diagnostic eventgenerated by one of the software subsystems.

The status of a diagnostic event is indicated by an ASCII stringwhich can have one of the following values:

• “Initialising”

• “Major error”

• “Minor error”

• “Not ready”

• “Ready”

• “Last wish”

• “Shutdown”

• “No status”The error code is assigned by the application when the statuschanges and precisely describes the cause of the error.


<10> Description <1> OS8ASCII 3 1 “BPP” (example)

<1> Current value <23> DATASTRUCTURE 29 1 (Includes the following threedefinitions)

<1> OS8ASCII 12 1 Status

<3> UI 1 1 Error code

<14> BINARY TIME 7 1 Time stamp (CP56Time2a)

Table 11.41 Directory entry for GIN 0x40 (xx)


11-71

The following table gives an example of the ASDU 10 “GenericData” that is transferred spontaneously for a diagnostic event.

0 0 0 0 1 0 1 0 Type Identification 10 DATA UNIT

1 0 0 0 0 0 0 1 Variable Structure Qualifier SQ=1, SQ_No.= 1 IDENTIFIER

Spontaneous <1> Cause Of Transmission COTREB500 CU/BU No. Common Address of ASDU <0 .. 59>

GEN <254> Function type FUN INFORMATION

Read value of single entry <244> Information number INF OBJECT<0> Return information identifier RII

1, 0, 0 Number of generic data sets NGD NO, COUNT, CONT40 H Generic identification number GIN01 H Example

Current value <1> Kind of description KODDATA STRUCTURE <23> DATA TYPE

29 DATA SIZE GDD1,0 NUMBER, CONT

<1> OS8ASCII DATA TYPE12 DATA SIZE GDD 11,0 NUMBER, CONT

“Major Error “ GID 1 (example)<3> UI DATA TYPE1 DATA SIZE GDD 2

1,0 NUMBER, CONTError code (UI1) GID 2<14> BINARY TIME DATA TYPE

7 DATA SIZE GDD 31,0 NUMBER, CONT

Time stamp (CP56Time2a) GID 3

Table 11.42 TYPE IDENTIFICATION: Generic data

Status information

All the status information relating to binary input and output sig-nals, internal signals (single-point indications - SPI) and switch-gear positions (double-point indications - DPI) that are con-figured in REB500 for transfer via IEC60870-5-103, but are notcovered by the compatible part of the IEC recommendation aretransferred as generic data. An entry is made in the table forevery event configured using REBWIN or REBCON for transfervia IEC 60870-5-103. Since there can be more events per type(SPI or DPI) than the maximum number of entries a group canhave (255), the system reserves additional groups as necessary.By this means, up to 1020 events per event type can be definedin the generic part.


11-72

Entry No. Group No. 66 (0x42) to

Group No. 69 (0x45)

Group No. 70 (0x46) to

Group No. 73 (0x49)

0 (Heading) Single-point indications Double-point indications

1 Indication #1 Indication #1


… … …


Table 11.43 Group for displaying status information (SPI and DPI)

The ASDU 10 “Generic data” is used with the following attributes:


COMMON ADDRESS OF ASDU 0 / 1..59 REB500 CU / REB500 BU

FUNCTION TYPE 254 GENeric function type

With the exception of the header (entry 0), the current values ofthe entries are not available on request. The response to thecorresponding generic read command is therefore COT 43“invalid data response to generic read command”.

Entries for single-point indications


<10> Description <1> OS8ASCII 24 1 "Single-point indications”

<1> Current value <3> UI 1 1 Number of SPI defined in this group



<10> Description <1> OS8ASCII 20 1 Event text defined by user

<1> Current value <23> DATA STRUCTURE 14 1 (Includes the following twodefinitions)

<9> DOUBLE POINTINFORMATION

1 1 OFF (1) / ON (2)




11-73

The following table gives an example of the ASDU 10 ‘GenericData’ that is transferred spontaneously for a single-pointindication.

0 0 0 0 1 0 1 0 Type Identification 10 DATA UNIT1 0 0 0 0 0 0 1 Variable Structure Qualifier SQ=1, SQ_No.= 1 IDENTIFIER

Spontaneous <1> Cause Of Transmission COTREB500 CU/BU No. Common Address of ASDU <0 .. 59>

GEN <254> Function type FUN INFORMATION


1, 0, 0 Number of generic data sets NGD NO, COUNT, CONT42 H Generic identification number Group <46H .. 49H>01 H Entry <1 .. 255>



<9> DOUBLE-POINT INFORMATION DATA TYPE1 DATA SIZE GDD 1

1,0 NUMBER, CONT0 0 0 0 0 0 <0 .. 3> GID 1

<14> BINARY TIME DATA TYPE7 DATA SIZE GDD 2

1,0 NUMBER, CONT


Table 11.46 TYPE IDENTIFICATION : Generic data

Entries for double-point indications


<10> Description <1> OS8ASCII 24 1 "Double-point Indications”

<1> Current value <3> UI 1 1 Number of DPI defined in thisgroup.



<10> Description <1> OS8ASCII 20 1 Event text defined by user

<1> Current value <23> DATASTRUCTURE 14 1 (Includes the following twodefinitions)

<9> DOUBLE POINTINFORMATIONWITHTRANSIENTAND ERROR

1 1 TRANSIENT (0) /

OFF (1) / ON (2) /

ERROR (3)




11-74

The following table gives an example of the ASDU 10 ‘GenericData’ that is transferred spontaneously for a double-pointindication.


Spontaneous <1> Cause Of Transmission COTREB500 CU/BU Unit No. Common Address of ASDU <0 .. 59>

GEN <254> Function type FUN INFORMATIONRead value of single entry <244> Information number INF OBJECT

<0> Return information identifier RII1, 0, 0 Number of generic data sets NGD NO, COUNT, CONT

46 H Generic identification number Group <46H .. 49H>01 H Entry <1 .. 255>



<11> DOUBLE POINT INFORMATION WITHTRANSIENT AND ERROR

DATA TYPE


0 0 0 0 0 0 <0 .. 3> GID 1<14> BINARY TIME DATA TYPE



Table 11.49 TYPE IDENTIFICATION : Generic data

Display of busbar differential currentsThe differential currents are displayed for each correspondingbusbar zone (1..32) (see Section 11.8.3.3).

The ASDU 10 ‘Generic data’ is used with the following attributes:


COMMON ADDRESS OF ASDU 0 REB500 CU

FUNCTION TYPE 254 GENeric function typeThe group number 75 (0x4B) is used to display busbardifferential currents and is therefore only assigned to the centralunit (CAA = 0).


<10> Description <1> OS8ASCII 21 1 "Differential currents”

<1> Current value <3> UI 1 1 Number of valid entries

Table 11.50 Directory entry for GIN 0x4B00 (header)


11-75

The number of valid entries corresponds to the number ofbusbar zones and thus limited to the range [1…32].

Each of the entries 1…32 in the group relates to a given busbarzone.


<10> Description <1> OS8ASCII 3 1 “SS1” example

<1> Current value <23> DATASTRUCTURE

2 1 (Includes the following twodefinitions)

<12> MEASURANDWITH QUALITYDESCRIPTOR

2 3,4 Field with 3 / 4 measurements

CP16 OV,ER,RES,MVAL


<9> Unit <1> OS8ASCII 1 1 “A”

<6> Factor <4> I 4 1 32 Bit integer

Table 11.51 Directory entry for GIN 0x4B (xx)

The description has a maximum length of 16 characters.The current value is a field with three (L1, L2, L3) or four (L1, L2,L3, L0) measurements and the associated time stamp. Theeffective number of measurements is determined by how theREB500 is configured.

OV Overflow This Bit is set to <1> whenever an overflowoccurs or the measurement is not assigned. Itis normally therefore set to <0>.

ER Error flag This Bit indicates whether a measurement isvalid or not (measurement valid <0>,measurement invalid <1>).

RES Reserved Spare for future use.

MVAL Contains the actual measurement in fixeddecimal point format.

The factor is a 32 Bit integer for calculating the original value.

The following table gives an example of the ASDU 10 ‘GenericData’ that is transferred spontaneously for displaying thedifferential currents of a given bus zone.


11-76


Spontaneous <1> Cause Of Transmission COTREB500 CU Common Address of ASDU <0>GEN <254> Function Type FUN INFORMATION


1, 0, 0 Number of generic data sets NGD NO, COUNT, CONT4B H Generic identification number Group01 H Entry <1 .. 32>



<12> MEASURAND WITH QUALITY DESCRIPTOR DATA TYPE2 DATA SIZE GDD 1

3,0 NUMBER, CONT 3 or 4 (including measurement L0)OV ER RES MVAL (4..8) GID 1a

MVAL (9..16)OV ER RES MVAL (4..8) GID 1b

MVAL (9..16)OV ER RES MVAL (4..8) GID 1c

MVAL (9..16)<14> BINARY TIME DATATYPE

7 DATASIZE GDD 21,0 NUMBER, CONT



11.8.5.5. Special information and instructions for configuring thecontrol system

Private range

None of the functions in the private range are used.

Common Address of ASDU

The fourth octet in the DATA UNIT IDENTIFICATION FIELD ofan ASDU determines the COMMON ADDRESS OF ASDU. Itnormally has to be the same as the station address on the linklayer. Exceptions are permitted where additional COMMONASDU ADDRESSES are needed because of multiple instancesof functions.

In the case of REB500, this exception allowed in the IECrecommendation is used in order to be able to address thecentral unit and the bay units via a single physical connection.

COMMON Address of ASDU - CAA

0 Central unit

1…59 Bay unit

255 Global address


11-77

Disturbance recorder, binary signal transferBinary signals transmitted in disturbance records only havenumbers and no designation. The assignment of numbers tosignal names is given in the COMTRADE file <filename>.CFGwhich can be uploaded, for example, from a bay unit usingREBWIN.

Signal configuration instructions

1 OC and CR events are not supported and if one isconfigured, the CIM module software will not start.

2 If none of the configured IBB protocols is set as a timesync source the CIM module software will not start.

3 Should the same logical signal be configured on twodifferent BIO modules in a bay unit, only one of themshould be relayed to the IEC-103 bus. A configurationthat is duplicated produces two indistinguishable eventswhich can cause some confusion. The response isreflected by REBWIN which also generates two events.

Cause of transmission

With the exception of 42 (generic writing command), all thepossible causes of transmission are supported in the commanddirection.

In the supervisory direction, they are all supported with theexception of 7 (test mode), 12 (local control unit) and 44 (returnconfirmation of a generic write command).


11-78

Type identification

The type identification defines the type of ASDU that has beentransferred.

TYPE Description

<1> time-tagged message

<2> time-tagged message with relative time

<5> Identification

<6> Time synchronisation

<8> General interrogation termination

<10> Generic data

<11> Generic identification

<23> List of recorded disturbances

<26> Ready for transmission of disturbancedata

<27> Ready for transmission of a channel

<28> Ready for transmission of tags

<29> Transmission of tags

<30> Transmission of disturbance values

<31> End of Transmission

Table 11.53 Information in the supervisory direction

TYPE Description

<6> Time synchronisation

<7> General interrogation (polling)

<10> Generic data

<20> General command

<21> Generic command

<24> Order for disturbance data transmission

<25> Acknowledgement for disturbance datatransmission

Table 11.54 Information in the command direction


11-79

Timeouts1 Protocol time-out < 50ms as defined in the IEC

recommendation applies for the protocol.2 When a command to upload the disturbance recorder

data is issued, the data have to be transferred from thebay unit to the central unit first before they aretransferred via the IEC bus. The timeout from the instantthe upload command is issued to the receipt of the datavaries in relation to the length of the disturbance record.The following applies:STS timeout < 2.5 minutes per 1 second of disturbancerecord data (4I+4U, 2400Hz)

3 Once the transfer of disturbance recorder data hasstarted, the timeout changes to:Transfer timeout < 1 Minute

11.9. Interfaces

11.9.1. Serial interfaces (RS 232)

A serial cable can be used for interfacing with the user interfacePC.

11.9.2. Fibre optic connection

Two electro-to-optical converters as well as two fibre opticalcables (single core) are needed for the connection betweenREB500 and the user interface PC. Depending on the distanceinvolved either optical cable with a synthetic or with a glass corecan be used.

For distances up to 30 m fibre optic cables with synthetic corescan be used. Complete adapter sets (2 converters incl. fibreoptic cable), can be ordered as accessories under the followingnumbers:

Type Order Number Identificationnumber

YX216a-1 (4 m) 7433 1640 - AA HESG448522 R1

YX216a-1 (10 m) 7433 1640 - BA HESG448522 R2

YX216a-1 (30 m) 7433 1640 - CA HESG448522 R3


11-80

For distances greater than 30 m, we recommend fibre opticcables with glass cores 62,5/125 µm and commercially availableconverters e.g. Hirschmann OZDV 2451 G (Hirschmann orderno. 943 299-021).

The converter on REB500 should be configured as DCE, and theconverter on the PC (incl. 25-pin on 9-pin adapter) as DTE.

11.9.3. Modem connection

In order to communicate between a PC with REBWIN to aREB500 via a telephone line, a modem is required on bothsides. Commercially available modems are to be used becauseABB does not supply these as accessories. We recommend thatyou study the manual of the modem carefully to ensure easycommissioning as well as problem free operation.

11.9.3.1. Remote access via modem

Modem connection

The modem is connected to the REB500 CMP SERIAL PORT 2by a standard 25-pin cable. Connections 2 (Tx) and 3 (Rx) arecrossed.

Caution: To exclude EMC interference, the modem may only beconnected via a commercially available galvanic RS232 insulator.

Modem configurationIn order to configure the modem, a terminal program on the PCis required (e.g. The standard Microsoft “Terminal” which comeswith every Windows version) This program must be configured tothe COM port to which the modem is connected (e.g. COM 1).

Both modems:

Firstly, the correct functioning of the modems must bechecked. On the command AT<Enter> the modem shouldrespond with OK (or 0).

The communication parameters must be configured to 9600Baud, 8 bit, no parity, 1 stop bit.


11-81

Software- and hardware handshakes must be disabled. Theappropriate AT command is to be taken from the modem’sinstruction manual.

REB500 modem:

This modem should be used in the “Automatic Call-back”mode. For this, most modems use the command AT SO=3,where 3 represents the number of calls

PC modem:

The signal DTR (Data Transmission Ready) must be deacti-vated in the modem on the PC side. This is necessary so thatoperation can be changed from “Terminal mode” to REBWINmode without interrupting the connection. The appropriate ATcommands are to be taken from the modem’s instructionmanual.

For the REB500 we recommend a modem with an automaticcall-back feature. When such a modem receives a call, thecaller has to identify himself by means of a password. Withpositive identification the connection in interrupted and themodem calls back a number belonging to the password. Thisensures that access to the protection device is only gainedfrom authorised sites. The passwords and their numbers areconfigured in the modem on REB500. The appropriate ATcommands are to be taken from the modem’s instructionmanual. Modem suppliers usually supply configurationsoftware which enables the easy setting of these passwordsand telephone numbers.

At the end, changes made must be saved in the internalmemory. The appropriate AT command is to be found in themodem’s instruction manual.


12-1

June 2000

12. GLOSSARY

12.1. Terms and Meaning ..............................................................12-2

12.2. Keyword index........................................................................12-8

12.3. External connections of REB500 (Example) ........................12-23

12.4. Important Information ...........................................................12-2712.4.1. Bay unit blocking signals......................................................12-2712.4.2. Reading central unit events..................................................12-2712.4.3. Reading the disturbance recorder ........................................12-2712.4.4. Time synchronisation ...........................................................12-2712.4.5. OC and CR events via IEC-103 ...........................................12-2712.4.6. TRC Minor Error 184............................................................12-2712.4.7. Reports ................................................................................12-2812.4.8. Disturbance records of switchgear positions........................12-2812.4.9. REBWIN V5.0 ......................................................................12-28

12.5. Test protocols.......................................................................12-29


12-2

12. GLOSSARY

12.1. Terms and Meaning

abbreviations

A Output

ALG_ General signal

ASIC Application specific integrated circuit

Backplane PCB or panel at the rear of an electronicequipment rack with the connectorsbetween the modules.

BB Busbar

BBP Busbar protection

BBP_ Busbar protection signal

BB zone Section of busbar bounded by circuit-breakers which can be isolated by theprotection

BFP Breaker failure protection

BFP_ Breaker failure protection signal

BPD Breaker pole discrepancy protection

BU Bay Unit

Bus segment Independently operating section of theprocess bus with its own CPU.

COMTRADE Data format for disturbance recorderaccording to IEEE C 37.111

Conductor Phase

CPU Central processing unit

CR Reductions factor due to the time constantof the power system

CU Central unit


12-3

Current comparison Comparison of differential and restraintcurrents i.e. the energy flowing towardsand away from a protected unit

DAC Data Accessor

Default Setting used if no other setting chosen

Device_Id ID of a communication unit (PCB)connected to a MVB segment

DIA Diagnosis

Differential Geometric sum of all the currents of aCurrent Idiff busbar section

DSP Digital signal processor

E Input

EFS Earth fault protection

EFS_ Earth fault protection signal

EFS_CPL Earth fault protection pick-up setting

Engineering System design and configuration by ABBPower Automation Ltd., or another au-thorized ABB company. Some parameterscannot be changed subsequently by theuser (e.g. The activation of licensedsoftware options)

Event memory Records changes in the status of binarysignals

EVR Event recorder

F Power system frequency

Faster signal input Internal signal processing approximately8ms as opposed to slower signals of 13ms

FE Bay unit


12-4

Front-plane PCB with plug-in base for moduleBus board

Ib Load current

IDiff Differential current

IE Current level setting

Irstnt Restrain current

IK Fault current

IKmin Minimun fault current of a feeder

IKMS Minimun fault current on a busbar

IKR Reduced fault current

IN Rated current

Increment Count forwards

INT Internal

Interbay bus Station bus

Irstnt zone

ITT Intertripping

IQ Transverse current

Jumper Bridge

K Stabilising factor

LCD Liquid crystal display

LED Light emitting diode

LON Interbay bus protocol

Mask/unmask A part of system or otem of plant that wasmasked using REBWIN (appears weakly in


12-5

the diagram. Eg. In preparation for a future extension of a station) has noInfluence on the protection.Master Maincontrol unit

Master Main control unit

Maximal prolongation

Minimum fault Fault current from the weakest source forcurrent Ikmin a fault at point Aat point A

MMK (Man-Machine-Communication) Localcontrol unit with LED`s, service buttonsand text display

MPB Multifunction process bus

N Rated ratio

n` Effective overcurrent factor

Neutral current I0 Geometric sum of the three phase currentsor the current measured by a neutralcurrent c.t

. Node_ID Number of the MVB bus segments withinREB500 (1……6)

OCDT Time-overcurrent protection

OCDT_ Time-overcurrent protection signal

OFC Optical fibre conductor

PB C:t. burden at IN

PC Personal computer

PE C.t. losses

Perturbograph Records currents, voltages and signals


12-6

Phase comparison Phase relationship between currentsmeasured in the same phase at differentlocations

PN C.t. rated power

REBWIN REB500 configuration and control programinstalled on a PC

Restrain current Absolute sum of all the currents of a bus

RV Reset ratio (overcurrent)

Signal setting Signal display followed by thecorresponding event

Slave Subordinate unit controlled by the master

Slow signal input Signal duration >128 ms plus contactbounce filter time

SPD Breaker pole discrepancy protection

stabilisation factor k Quotient of differential (operating) andrestraint currents

STS Disturbance recorder

STS_ Disturbance recorder signal

SVS Breaker failure protection

SVS_ Breaker failure protection signal

SYS_ System signal

System wide In the central unit and all bay units

t1 Delay t1 (SVS)

t1d Timer t1 tolerance (SVS)

t2 Delay t2 (SVS)

t2d Timer t2 tolerance (SVS)


12-7

ta Rise time (maximum prolongation)

tCB Circuit-breaker opening time

te Contact bounce filter and internalprocessing time

th Prolongation time (maximun)

Time stamp Date and time

TN Power system time constant at the busbars

to Operating time (maximum prolongation)

tRes Back-up time

Trigger Event that starts the disturbance

tV Reset time (SVS current measurement)

UMZ Time-overcurrent protection

UMZ_ Time-overcurrent protection signal

WINEVE ABB disturbance recorder data evaluationprogram

∆φ Phase shift (phase comparison)

∆φmax Tripping phase shift (phase comparison)


12-8

12.2. Keyword index

A see under Chapter

Administrator 4

Ambient conditions 6

Analogue section 3

Analogue/digital converter 3

Ancillary function 3

Application 4

Application example 5

Arc 3

Arrow button 3 / 4

Assembly replacement 9

Assignment 3

Auxillary contact 3

Auxillary supply voltage 7

BBack plate 3

Back-up equipment 8

Batteries 3

Baud 3

Bay unit 3

Bay unit 3

Bending radius 6

Binary channels 5

Binary inputs 3

Binary input-output module 3

Binary outputs 3

Block diagram 3

Blocking reaction 3

Blocking scheme 3


12-9

Blocking 8

Breaker back-up protection 11

Breaker pole discrepancy protection 11

Bus controller 3

Bus segments 3

Busbar image 3

Busbar protection 5

Busbars 3

Bus-tie breaker 3

Buttons 3

Bypass isolator 5

Bypass operation 5

CCabinet/cubicle 6

Cabinet/cubicle earth 6

Calculations 5

Cancel 4

Central installation 3

Central unit 3

Circuit-breaker 3

Circuit-breaker designation 5

Circuit-breaker inspection 5

Circuitry 6

Clock time 3

Close 4

CMP 3

Communication interface 3

Communications parameter 8

Compensated 3

COMTRADE 4


12-10

CSP 3

C-Button 3

Configuration 4 / 5

Contact bounce filter 3

Contact mode 5

Contacts in series 3

Control 4

Control unit 8

Convention 3

Current comparison 3 / 5

Current transformer 3 / 5

Cycle 3

DData bases 4

Debug mode 4

Device structure 5

Diagnosis 3

Differential Current 3

Differential current alarm 3 / 5 / 8

Differential current measurement 3

Distributed installation 3

Double busbar 3

Double busbar with transfer bus 3

EEarthing bars 6

E-Button 3

Electrically insulated 3

Enable/disable 3

End fault protection 11

Event buffer 3


12-11

Event configuration 5

Event list 4

External fault 3

External fault with current transformer saturation 3

External release 3

Extras 4

FFAIL 3

File 4

Flashover gap 3

Free star-point (isolated) 3

Front-plane bus board 3

Function abbreviations 3

Fundamental frequency components 3

FUSE 3

Fuse 3

GGround concept 6

HHardware interface 9

Hierarchy 3

IIBB 11

IEC 60870-5-103 11

Impedance grounded 3

Input range 3

Inputs 3

Inspection 3

Install location 6


12-12

Installation mode 4

Installation mode 3

Interface 3

Interface module 3

Interfaces 11

Interferences 9

Internal fault 3

Intertripping 3

Intertripping system 3

Isolator alarm 3 / 8

Isolator designation 5

Isolator replica 3

Isolator supervision 3

JJumper J1 3

Jumper J20 3

Jumper J22 3

LLAN 3

Local control unit 3

LON 11

Loss of supply 3

Low voltage check 3

MMain contact 3

Main menu points 3

Main window 4

Maintenance 3

Master CPU 3

Master bus administrator 3


12-13

Maximum amount 3

Maximum prolongation 3

MBA 3

Measuring principle 3

Menu structure 3

Miniature circuit-breaker 3

Minimal contact bounce filter 3

Minimum 4

Minute pulse 3

MMK 3

Modem 7

Modem link 3

Modem link 7

Mounting version 3

Mouse 4

NName category 3

Network earthing 3

Neutral current supervision 3 / 11

Neutral measurement 11

Normal operation 8

OObject-oriented model 3

Off line 4

OK 4

On/off switch 3

Operating in parallel 3

Operator program 4

Optical 3

Optical fibre cable 6


12-14

Optical fibre conductor 3

Optical fibre conductor cable 3

Optical interface 3

Optical receiver 3

Optical star coupler 3

Opto-coupler 3

Opto-coupler number 5

Opto-electrical converter 3

Output power 3

Output relay 3

Output voltage 3

Overcurrent release 3

PPassword 4

PC 3

Perturbograph 5 / 11

Phase angle 3

Phase comparison 3

Plant diagram 5

Plant diagrams 3

Plant objects 3

Power supply module 3

Power system frequency 3

Primary supply 7

Process bus 3

Protection zone 3

Push buttons 4

RREBWIN 3 / 4

Receiver 3


12-15

Reclaim time 5

RE-commissioning 9

Record 5

Redundancy 3

Relay output 5

Release 11

Release the trip command 3

Remote control 11

Remote tripping 5

Repair 9

Reports 4

Reset 8

Restart 8

Restore 4

Restraint current 3

Restraint factor 3

Reverse current 5

Ring bus configuration 3

RS485 3

RUN 3

SSampling rate 3

SBA 3

SCON 3

Screen holder 6

Secondary injection 7

Security tip 2

Self monitoring 3

Sender / receiver 3

Serial interface 3


12-16

Serial interface 3

SERIAL PORT 2 3

Setting 4

Setup 4

Shipment damage 7

Signal 3

Signal concept 3

Signal contact 3

Signal duration 5

Signal nomenclature 3

Signal number 3

Signal output 3

Signal recording 3

Signal response 3

Simulation mode 4

Single busbar 3

Slave bus administrator 3

Slave CPU 3

Solidly grounded 3

Stability 3

Stability test 7

Stand-by operation 3

Star coupler module 3

Start-up phase 8

STAT 3

Station control system 3

Station ground 6

Station layout 3

Stopbit 3

Storage 10

Supervision 3


12-17

Switching ban 3

Switching sequence 7

System response 5

TTechnical overview brochure 3

Test 4

Test 4

Test generator 3 / 4

Test mode 3

Time delay 5

Time stamp 3

Time synchronization 3

Time-overcurrent protection 11

Tolerance 12

Transformer terminals 3

Transition module 3

Transverse current 5

Trigger condition 5

Trip redirection 8

Tripping channels 3

Tripping commands 3

Tripping contacts 3

Tripping threshold 3

Tripping time 3

Trips 8

T-zone 3

UUn-install 4

Upgrade 3

User software 3


12-18

VView 4

VME 3

Voltage transformer inputs 3

Voltage transformer terminals 3

WWaste disposal 10

ZZone trip 3


12-19

Numerics see under Chapter

1½ Circuit-breaker configuration 3

1½ Breaker scheme 5

11110 5

11205 5

11201 5

11215 5

11505 5

11510 5

11530 5

11605 5

11610 5

11615 5

11620 5

11655 5

11660 5

11765 5

13205 5

13605 5

13705 5

13710 5

13740 5

14205 5

15210 5

16705 5

17205 5

17710 5

21105 5

21110 5

21115 5

21305 5


12-20

21405 5

21410 5

21805 5

21810 5

21815 5

22405 5

23105 5

23110 5

23305 5

23310 5

23315 5

23320 5

23325 5

23330 5

23335 5

23405 5

24105 5

24305 5

24405 5

25105 5

25305 5

25405 5

26805 5

26810 5

26815 5

26820 5

27105 5

27305 5

27405 5

31105 5

31205 5


12-21

31210 5

31215 5

31505 5

31805 5

31810 5

31815 5

31820 5

31825 5

32205 5

33210 5

34215 5

35220 5

36705 5

37205 5

41305 5

41310 5

41405 5

41410 5

41505 5

41805 5

41810 5

41815 5

41820 5

41825 5

41830 5

41835 5

42305 5

42310 5

42315 5

42320 5

42325 5


12-22

42405 5

43305 5

43310 5

43405 5

44305 5

44405 5

45305 5

45405 5

45805 5

47305 5

47405 5

500BIO01 3

500BU02 3

500CIM04 3

500CMP04 3

500CSP04 3

500IPS01 3

500MBA01 3 / 9

500PBIO1 3

500PSM03 3

yellow LED 3

green LED 3

red LED 3

500SCM01 3

500TRM02 3

500TRM03 3


12-23

12.3. External connections of REB500 (Example)

The connection diagrams of REB500 are function specific anddrawn according to the current norm: plus up, minus down.

The diagrams that follow, show the correlation between theexternal connections. Additionally, some recommendations (nonbinding) are made. The connection of the current transformersalways leads to questions. In principle, descriptions like P1 andP2 etc. don`t play any role. The connection of the bus-tie breakercurrent transformers deserves special attention and is shown asan example.

An example is given of the connection between the battery andthe REB500 including the connected circuits. In the example, it isalso recommended how the circuits should be protected.L1

L2L3

L1 L2 L3

-U Batt.

Close command

Q0

T1

Q0 Open Q0 Closed Q0 (Close command)

Bay unit

-F391 A9 A10 A13 A14

GROUP 3 A11 A12 GROUP 4 A15

OC05 OC06 OC07 OC08

-U Batt.

+U Batt.

HEST 005049 C

Figure 12.1 Typical connection diagram for circuit-breakerimage


12-24

I1

I2 I

3

I4

I5

I6

I7

I8

I9

I

10

I11

I12

-F39

1

1A

5A

N

IL1

IL2

IL3

IL0

1A

5A

N1

A 5

A N

1A

5A

N

I1

I2 I

3

I4

I5

I6

I7

I8

I9

I10

I11

I1

2-F

391

1A

5A

N

IL1

IL2

IL3

IL0

1A

5A

N1

A 5

A N

1A

5A

N

I1

I2

I3

I4

I5

I

6

I7

I8

I9

I1

0 I1

1 I

12

-F3

91

1A 5

A N

IL1

IL2

IL3

IL0

1A

5A

N1A

5A

N

1A

5A

N

-F39

1A

1A

2A

5A

6

GR

OU

P 1

A3

A4

GR

OU

P 2

A7

OC

01O

C02

OC

03O

C04

L1 L2 L3 L1 L2 L3

I II

L1 L2 L3 L1 L2 L3

I II

L1L2

L3

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ase

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HEST 005046 C

Figure 12.2 Typical connection diagram (isolator, current trans-former) for a feeder and a bus-tie breaker with atransformer (variant with 2 transformers)


12-25

25A

10A

10A

Central unitPower supply1 (2)

Bay unitBU1

Power supply1 (2)

1 (2)

1 (2)

1 (2)

Battery B3

BatteryB1

Battery B2

+

-

+

-

+

-

Station DC supplyShort circuit protection

BU2

BU3

BU4

Upto 6 BU's

Next 6 BU's

DC supply shortcircuit protection

Wiring1,5mm2

Redundant Power Supply (Option)

Trip circuit Coil 1BU1 + other protection

BU1 + other protection

BU2

BU2

Isolator imageBU1

Isolator imageBU2

IndicationIf B1 fails during operation then theindications are still available from theB3 power supply.Information!!

Trip circuit Coil 2

Trip circuit Coil 1

Trip circuit Coil 2

10A

If B1 fails during operation, then thelast isolator image will be valid aslong as the image does not change.

HEST 005048 C

Figure 12.3 Typical connection diagram of the DC distribution(battery supply) for a centralized REB500


12-26

Wiring1,5mm2

Redundant Power Supply (Option)

10ACentral unit

1 (2)

Bay unitBu1

Power supply1 (2)

4A

OtherProtection

4A

4A

1

1

1

(2)

(2)

(2)

BU2Power supply

BU3

Power supply

BU4

Power supply

Trip circuit Coil 1BU1 + other protection

BU1 + other protection

BU2

BU2

Isolator imageBU1

Isolator imageBU2

IndicationsBattery B3

+

-

+

-

+

-

Trip circuit Coil 2

Trip circuit Coil 1

Trip circuit Coil 2

Battery B2

Battery B1

Other BU's

If B1 fails during operation the isolatorimage last know will be valid aslong as the image does not change

If B1 fails during operation thenthe indications are still availablefrom the B3 power supply.Information!!

Station DC supplyshort circuit protection

DC supply shortcircuit protection

HEST 005047 C

Figure 12.4 Typical connection diagram of the DC distribution(battery supply) for a decentralized REB500


12-27

12.4. Important Information

(Software version V5.00)

12.4.1. Bay unit blocking signals

If the input “31210_Block output relays” is set on the central unit,the bay units do not process the protection functions BFP, EFPand OCDT locally. The associated blocking signals “23405_BFPblocked”, “24405_EFP blocked” and “25405_OCDT blocked”therefore reset.

12.4.2. Reading central unit events

Events stored in the central unit remain intact in the event of asupply failure for at least 24 hours. Should the supply beinterrupted for a longer period or the energy reservoir bedefective, the contents of the event memory are invalid. If theyare uploaded by REBWIN when the system is in operation again,the invalid data can block the protection and cause it toreinitialise. To avoid this, the event memory must be deleted insuch cases before it is read.

12.4.3. Reading the disturbance recorder

Should the last available buffer memory (configured as FIFO)become full while reading the disturbance recorder data, thedisturbance recorder function is disabled and has to be explicitlyenabled again.

12.4.4. Time synchronisation

The minute impulse cannot be used to synchronise the time inthe various units if one of the two IBB protocols is configured.

12.4.5. OC and CR events via IEC-103

OC events (any physical opto-coupler input regardless of signal)and CR events (any physical relay output regardless of thesignal configured) are not supported by the IEC-103 protocol(generic). Therefore if they are configured in spite of this, the500CIM01 software will not start.

12.4.6. TRC Minor Error 184

Most hardware components are equipped with a non-volatilememory containing what is termed traceability data such as dateof production, index serial number etc. The consistency of thesedata are checked whenever REB 500 is started and a TRCminor error 182 message generated should an error be found.


12-28

12.4.7. Reports

A printer driver must be installed under Windows before it ispossible to display pre-defined reports on the screen. The printerdoes not, however, have to be actually connected to the PC.

The reports preview cannot display pages with numbers higherthan 99.

12.4.8. Disturbance records of switchgear positions

The disturbance recorder does not record the positions of circuit-breakers and isolators, because when fitted with two auxiliarycontacts (for CLOSED and OPEN) they can have more than twostatuses (open, in motion, closed and undefined). The distur-bance recorder functions and the evaluation software can onlyprocess binary signals (i.e. signals that only have two possiblevalues).

A possible alternative is to configure one of the “x_Start DR_n”signals to be in parallel with the CLOSED auxiliary contact onthe isolator.

12.4.9. REBWIN V5.0

In Section 4.5.35 Tools / Version it’s written, that the user hasthe possibility of changing the index and its description. Adding aversion description text longer than 100 characters for „revisionindex information“ will cause a program crash.

In Section 5.4.3 Busbar protection (settings and calculations) thesetting parameter for the stabilizing factor k are given. If inWINDOWS the „Decimal Symbol“ in „Regional Settings“ is set tocomma, the value of k cannot be set. K can only be setaccording to U.S. standard, i.e. by means of a point, e.g. 0.8 andnot 0,8.


12-29

12.5. Test protocols

Test record type REB500 (test bay)

(subject to alterations)

Test sheet type REB500 (commissioning)

(subject to alterations)


12-30

ABB Power Automation AG/LtdTEST PROTOKOLL / Test Record:

Änderung:

-

Seite:

1/16

REB500

Fabrikations-Nr. ZE.......

Stammdaten / Regular data

KundeClient ...............................

AnlageInstallation .......................

SchutzobjektProtected Object .............

Bestell-Nr.Order-No. ........................

Geräte-Nr.Equipment-No. ................

Schema-Nr.Diagram-No.....................

Fabrikations-Nr.Fabrication-No.................

Nenndaten / Nominal data

NetzspannungMain voltage ......................... VAC

NennstromNominal current .................... A

NennspannungNominal voltage.................... V

NetzfrequenzNominal frequence ............... HZ

HilfsgleichspannungAuxiliary voltage ................... VDC

Spannung Eing.-BefehleInput-Signal voltage.............. VDC

GeprüftTested

FreigegebenReleased

PrüfdatumTestdate

00-11-02Kundenabnahme durch ...Factory acceptance test by ...

AbnahmedatumDate of FAT

Edit: 00-06-09 Based on: File HEADPROT_c_r5 Mod. C


Änderung:

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REB500Durchgeführte Tests / Checks done

1. Mechanische KontrolleMechanical check ..................................................................................................................................

2. Übereinstimmung mit den ArbeitsdokumentenMarking, correct items included.............................................................................................................

3. AnlageerdungProtective earthing.................................................................................................................................

4. Relais und EinschübeRelays and plug-in units ........................................................................................................................

5. Hochspannungsprüfung und IsolationswiderstandDielectric test and insulation resistance ................................................................................................

KreisCircuit

HochspannungHigh voltage

WiderstandResistance

1 WechselstromAC-current

2 WechselspannungAC-voltage

3 GleichspannungskreiseDC-circuit

4 Auslösung und SignaleTripping and signals

5 EingangsbefehleInput commands

6 NetzeingangMain voltage

7 ErdeEarth

Tested according to IEC 255-5, Class C (1977)

6. SpeisungSupply....................................................................................................................................................

7. SchnittstellenInterfaces...............................................................................................................................................

8. FunktionsprüfungOperational test .....................................................................................................................................

9. Zubehör und ReservematerialAccessory and spare part......................................................................................................................

10. SchlusskontrolleFinal check ............................................................................................................................................

Based on: File HEADPROT_c_r5 Mod. C


Änderung:

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REB500Fabrikations-Nr.Fabrication-No................................................

Benützte Messmittel / Measurment instruments used

BezeichnungDesignation

TypType

Inventar-Nr.Inventory-no.

BemerkungRemark

Multimeter Ana. Unigor 3n 032320Multimeter Dig. Fluke 85 032140Timer TM200 I-ES110475Multimeter Ana. Unigor 1n 021188Multimeter Ana. Unigor 3n 015042Multimeter Dig. Fluke 8024A 015143Multimeter Dig. Fluke 85 110302Zeitmesser TM 2 026335Multimeter Dig. Fluke 85 110304Timer TM200 I-ES110476Hochsp.Prüfgerät P 6S 023320Isolationsmesse Metriso 5000 020285Prüfturm 1 REB500 APTS-VISTAR 110425Prüfturm 2 REB500 APTS-VISTAR I-ES110481Hochsp. Prüfst. P 5S/Metr. 5000 007146Isolationsmesse Metriso 500 020273Multimeter Ana. Unigor 3n 009123Multimeter Dig. Fluke 8024A 018999Multimeter Dig. MA 5D 016887Zeitmesser TM 2 026334A-Quelle + Timer Harald Programma 110477

Based on: File HEADPROT_c_r5 Mod. C


Änderung:

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REB500Fabrikations-Nr.Fabrication-No................................................

Einstellungen SSS / settings BBP:

Prüfungen SSS / tests BBPIn Beilagen protokolliert / recorded in enclosures .................................................................................................

Zusätzliche Funktionalitäten / additional functions:Ext. Auslösung / ext. Trip ......................................................................................................................................

konfiguriert und geprüftconfigured and tested

Ext. Freigabe / ext. release ...................................................................................................................................konfiguriert und geprüft

configured and tested

Auslöseumleitung / trip redirection ........................................................................................................................konfiguriert und geprüft


Trenneralarm / isolator alarm................................................................................................................................konfiguriert und geprüft


Revision, Wartung / revision, maintenance...........................................................................................................konfiguriert und geprüft


Blockierungen / blocking .......................................................................................................................................konfiguriert und geprüft


Überstromfreigabe / Overcurrent check................................................................................................................konfiguriert und geprüft


Unterspannungsfreigabe / Undervoltage check....................................................................................................konfiguriert und geprüft


Einstellungen SSS / settings BBP:Kurzschlusstrom / Phase fault current Ikmin................................................................................................ AKurzschlusstrom L0/ Phase fault current L0 Ikmin....................................................................................... Ak-Faktor / k-factor............................................................................................................................................... Differenzstromalarm / Differentialcurrent alarm Idiff ................................................................................... %Zeitverzögerung Idiff / Time delay Idiff ............................................................................................................. sTrennerlaufzeit / Isolator running time........................................................................................................... s

Ansprechwert Überstromfreigabe >I / pick up value overcurrent check >I ............................................... x INAnsprechwert Unterspannungsfreigabe <U / pick up value Undervoltage check <U ............................ x UN

Based on: File r5pc_BBP Mod. D


Änderung:

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Seite:

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REB500Fabrikations-nr ZE / Fabrication-no CU

Kupplungsblockierung / Blocking of the coupler:

KupplungCoupler

Schalter offenBreaker open

TrennerIsolators

AbgangFeeder

Parallelbetriebparallel operation

BemerkungRemark

Based on: File r5pc_blockcoupler Mod. C


Änderung:

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Seite:

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Feeder1

BB1

BB2

Feeder2

Coupler

Fault

Feeder1

BB1

BB2

Feeder2

Coupler

Fault


Kupplungsfunktion / coupler function:

Externer Fehler / external fault.................................................................. .................................................Kupplung/coupler Keine Auslösung/no trip

Kupplung mit 1/2 Wandler / coupler with 1/2 ct:

Diagrammbeschreibung / description of diagram

BB1: .................................

BB2: .................................

Abgang/Feeder 1: ........................

Abgang/Feeder 2: ........................

Kupplung/Coupler: .......................

Fehlerhafter Schienenteil löst unverzögert aus / faulty busbar trips immediatly ...................................................Mitnahme auf umliegende Schienenteile / intertriping on surrounding busbars ...................................................Kupplungsnachholzeit / coupler reclaim time......................................................... ms ms

eingestellt/set gemessen/measured

Diagrammbeschreibung / description of diagram

BB1: .................................

BB2: .................................

Abgang/Feeder 1: ........................

Abgang/Feeder 2: ........................

Kupplung/Coupler: .......................

Fehlerhafter Schienenteil löst unverzögert aus / faulty busbar trips immediately .................................................Mitnahme auf umliegende Schienenteile / intertripping on surrounding busbars .................................................Kupplungsnachholzeit / coupler reclaim time......................................................... ms ms

eingestellt/set gemessen/measured

( )cycletripsetmeasure tttt ⋅++≈ 2 tcycle = 8 ms

Kupplung mit 2 Wandler / coupler with 2 ct‘s:

Fehler zwischen Wandlern / fault between ct‘s ...........................................................................................Kupplung/coupler sofortige Ausl. beide Seiten/immediate trip both sides

Based on: File r5pc_coupfunc Mod. C


Änderung:

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CB ACT2 CT3 CT4 CT5 CT6CT1

1.

Busbar I Busbar IIDTT 1 DTT 2

2. 3. 4. 5. 6. 7. 8. 9. 10.

CB B CB C

DTT: direct transfer tripCT: current transformerCB: circuit breaker


1 ½ Sammelschiene / 1 ½ bus system

Wandler vorhanden / CT‘s availableCT1 CT2 CT3 CT4 CT5 CT6

Fehler/ Fault

CB A DTT 1 CB B DTT 2 CB C BusbarI

BusbarII

Bemerkung / Remark

1 CB A closed and faulty CB A open

CB B closed and faulty4 CB A closed and faulty CB B open

CB C closed and faulty7 CB B closed and faulty CB C open10 CB C closed and faulty

DTT: direkte Fernauslösung CT: Stromwandler CB: LeistungschalterBusbar: Sammelschiene closed and faulty: geschlossen und ein Kurzschluss

open: geöffnet

Bemerkungen / Remarks:

Based on: File r5pc_diameter Mod. C


Änderung:

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Seite:

8/16


K-Wert Messung / K-Value measurement:

K-Wert / K-Value: K = ( )( )II

ΣΣ

Einstellung / Setting: 0.8

PhasePhase

SchieneBusbar

Abgang 1Feeder 1

Strom 1Current 1

Abgang 2Feeder 2

Strom 2Current 2

K-WertK-Value

AbweichungDifference

L1 A A %L2 A A %L3 A A %

PhasePhase

SchieneBusbar

Abgang 1Feeder 1

Strom 1Current 1

Abgang 2Feeder 2

Strom 2Current 2

K-WertK-Value


L1 A A %L2 A A %L3 A A %

PhasePhase

SchieneBusbar

Abgang 1Feeder 1

Strom 1Current 1

Abgang 2Feeder 2

Strom 2Current 2

K-WertK-Value


L1 A A %L2 A A %L3 A A %

PhasePhase

SchieneBusbar

Abgang 1Feeder 1

Strom 1Current 1

Abgang 2Feeder 2

Strom 2Current 2

K-WertK-Value


L1 A A %L2 A A %L3 A A %

PhasePhase

SchieneBusbar

Abgang 1Feeder 1

Strom 1Current 1

Abgang 2Feeder 2

Strom 2Current 2

K-WertK-Value


L1 A A %L2 A A %L3 A A %

PhasePhase

SchieneBusbar

Abgang 1Feeder 1

Strom 1Current 1

Abgang 2Feeder 2

Strom 2Current 2

K-WertK-Value


L1 A A %L2 A A %L3 A A %

PhasePhase

SchieneBusbar

Abgang 1Feeder 1

Strom 1Current 1

Abgang 2Feeder 2

Strom 2Current 2

K-WertK-Value


L1 A A %L2 A A %L3 A A %

Based on: File r5pc_kvalue Mod. C


Änderung:

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Mitnahme / Intertriping:

SchienenteilBusbar sect.

Ref AbgangRef Feeder

Abgang / KupplungFeeder / Coupler

Fehler internInternal fault

Fehler externExternal fault

BemerkungRemark

Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip Trip No Trip

Trip: Auslösung No Trip: Keine Auslösung Based on: File r5pc_intertrip Mod. C


Änderung:

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Störschreiber / disturbance recorder:

Konfiguriert / configured ........................................................................................................................................

Aktiviert / aktiv .......................................................................................................................................................

Einstellungen / settings

Anzahl Aufzeichnungen / number of records ...........................................................................................................2

Bei Speicherüberlauf / in case of event overflow .................................................... .........................................FIX FIFO

Grundfrequenz / main frequency ............................................................................ .........................................50 Hz 60 Hz

Analoge Kanäle / analog channels.......................................................................... .........................................4 x Strom/current 4 x Spannung/voltage

Binäre Triggersignale / binary trigger signals.......................................................... .........................................konfiguriert nicht konfiguriertconfigured not configured

Abtastrate / sampling frequency

Grundfrequenznominal frequency

50 Hz 60 Hz

Abtastratesampling rate

600 Hz 1200 Hz 2400 Hz 720 Hz 1440 Hz 2880 Hz

Aufzeichnungs-Dauerrecording duration

1.5 s st st3 s st st6 s st o1 st o110 s o2 o212 s o1 o120 s o2 o224 s o1 o140 s o2 o2

st = Standard o1 = Option 1 o2 = Option 2

Based on: File r5pc_distrec Mod. C


Änderung:

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Schalterversager-Schutz SVS / breaker failure protection BFP

Prüfung SVS / tests BFP:

Ext. Anregung / ext. start ......................................................................................................................................konfiguriert und geprüft


Ext. Anregung ohne Strom / ext. start without current ..........................................................................................konfiguriert und geprüft


Auslösung SVS nach T1 / trip BFP after T1..........................................................................................................konfiguriert und geprüft


Auslösung SVS nach T2 / trip BFP after T2..........................................................................................................konfiguriert und geprüft


Fernauslösung SVS / remote trip BFP ..................................................................................................................konfiguriert und geprüft


Blockierung SVS / block BFP................................................................................................................................konfiguriert und geprüft


Signalisierung SVS / signalisation BFP.................................................................................................................konfiguriert und geprüft


Einstellungen SVS / settings BFP:

SVS aktiv in Feld / BFP activ in feeder .............................................................................................alle / all

Verzögerungszeit / time delay T1 100 ms .............................................................................................aktiv / activ

Verzögerungszeit / time delay T2 200 ms .............................................................................................aktiv / activ

Ansprechwert SVS / current setting BFP ....................................................................................................... 1.2 x IN

Fernauslösung konfiguriert nach / remote trip configured after .............................. .........................................T1 T2

Logik Typ / logic type .............................................................................................. ................ ....................1 2 3

Based on: File r5pc_BFP Mod. C


Änderung:

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Seite:

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Endfehler-Schutz / end fault protection:

Prüfung EFS / tests EFP:

Auslösung EFS / trip EFP .....................................................................................................................................konfiguriert und geprüft


Mitnahme EFS / interrip EFP ................................................................................................................................konfiguriert und geprüft


Fernauslösung EFS / remote trip EFP ..................................................................................................................konfiguriert und geprüft


Blockierung EFS / block EFP ................................................................................................................................konfiguriert und geprüft


Signalisierung EFS / signalisation EFP .................................................................................................................konfiguriert und geprüft


Einstellungen EFS / settings EFP:

EFS aktiv in Feld / EFP activ in feeder................................................................ .......................................alle / all

Ansprechwert */ pick up value * ..................................................................................................................... 1.2 x IN

Ansprechverzögerung bei Schalteröffnung/ pick up value time delay on opening cb................................ ms

* Nur einstellbar durch ABB Power Automation AG / can just be set by ABB Power Automation Ltd

Based on: File r5pc_EFP Mod. C


Änderung:

-

Seite:

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Überstrom-Schutz / overcurrent protection:

Prüfung UMZ / tests OCDT:

Auslösung UMZ / trip OCDT .................................................................................................................................konfiguriert und geprüft


Fernauslösung UMZ / remote trip OCDT ..............................................................................................................konfiguriert und geprüft


Blockierung UMZ / block OCDT............................................................................................................................konfiguriert und geprüft


Signalisierung UMZ / display OCDT .....................................................................................................................konfiguriert und geprüft


Einstellungen UMZ / settings OCDT:

UMZ aktiv in Feld / OCDT activ in feeder ........................................................... .......................................alle / all

Zeitverzögerung / time delay ...................................................................................................................... ms

Ansprechwert / pick up value .................................................................................................................... x IN

Based on: File r5pc_OCDT Mod. C


Änderung:

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Seite:

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Schalterpoldiskrepanzschutz/ Circuit-breaker pole discrepancy protection:

Prüfung SPD / tests PDF:

Ansprechen SPD / operate PDF ...........................................................................................................................konfiguriert und geprüft


Blockierung SPD / block PDF ...............................................................................................................................konfiguriert und geprüft


Signalisierung SPD / signalisation PDF ................................................................................................................konfiguriert und geprüft


Einstellungen SPD / settings PDF:

Diskrepanzfaktor / Discrepancy factor ................................................................................................... x Imax

Zeitverzögerung / time delay ...................................................................................................................... ms

Ansprechwert / pick up value .................................................................................................................... x IN

Based on: File r5pc_


Änderung:

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IEC 60870-5-103 Schnittstelle / interface

Aktivierung / activation ............................................................................................ .........................................IBB 1 IBB 2

CIM Node ID; Device ID............................................................................................ 7............................................0Node Device

IEC-103 address ................................................................................................................................................

Baudrate....................................................................................................................................................................

Kommunikation geprüft / communication tested ...................................................................................................Mit IEC-103 Simulations-SW / by IEC-103 simulation tool

Bemerkung / remark:

LON Kommunikation / communication

Aktivierung / activation ............................................................................................ .........................................IBB 1 IBB 2

CIM Node ID; Bus line......................................................................................... .................................... Node bus line

Clock address ....................................................................................................................................................

Clock warning address.......................................................................................................................................

Sync. source .........................................................................................................................................................

Kommunikation geprüft / communication tested ...................................................................................................Mit LON Tool / by LON tool

Bemerkung / remark:

Based on: File r5pc_COMM Mod. C


Änderung:

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Seite:

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Datenblatt / data sheet 1MRB 520256-Bde / Ben (März / March 2000)Prüfanweisung / test instruction 1KHF 060260/A

Konfiguration / Configuration:

Konfigurierte Funktionen / functions configured:Sammelschienenschutz SSS / busbar protection BBP.........................................................................................L0-Messung / L0 measurment ..............................................................................................................................Schalterversagerschutz SVS / breaker failure protection BFP .............................................................................Endfehlerschutz EFS / end fault protection EFP...................................................................................................Überstromzeitschutz UMZ / time-overcurrent protection OCDT ...........................................................................Schalterpol-Diskrepanz-Schutz SPD / CB pole discrepancy function PDF ..........................................................Störschreiber STS/ disturbance recorder DRR.....................................................................................................LON-Interface / LON interface ..............................................................................................................................IEC-Interface / IEC interface .................................................................................................................................? / ? .......................................................................................................................................................................

Softwareversionen / software versions:REBWIN (MMI) ...................................................................................................................................................5.00REBCON (Config.-SW).......................................................................................................................................5.00REBSYS (Firmware) ...........................................................................................................................................5.00SiMon (Base-SW) .....................................................................................................................3.41 ..................3.43

CU BU

SS-Konfiguration / BB configuration:Anzahl Schienen / number of buses ........................................................................................................................2Anzahl Abgänge bestückt, Reserve / number of feeders equipped, spare..........................................................0, 0Anzahl Längstrenner / number of section isolators ..................................................................................................0Anzahl Kupplungen bestückt, Reserve / number of coupler equipped, spare ...... 0, 0................ ....................

Anzahl/number 1 ct 2ct

REB500 Aufstellung / REB500 setting:Zentral / centralized.......................................................................................................................... .....................Dezentral / decentralized ......................................................................................................................................

Aufbau Einheiten / structure of units:Redundante Speisung ZE / redundancy supply CU .............................................................................................Redundante Speisung FE / redundancy supply BU..............................................................................................BIO in ZE / BIO in CU ..............................................................................................................................................1

Konfigurationsdatei / setfile:Name / name .......................................................................................................................................... .mdb

ZE=Zentraleinheit .........CU=Central Unit ..........FE=Feldeinheit ............ BU=Bay Unit................ SS=Sammelschiene.....BB=Busbar

Based on: File r5pc_config Mod. D

TEST SHEET Page:STATION:

Reb5_E1203_Testsheet.doc / 00-07

Busbar protection type REB500 Commissioning BAL/IBS

Date: Signature:

Client

Date: Signature:

Check list

Kind of check Remarks Page

General specification

Check of transport damage

Visual check of external wiring

Check of cubicle / relay earthing

Check of supply voltage (DC)

Check of settings (calculated by ....)see sep.print out

Check of current transformer circuits

Check of voltage transformer circuits

Check of allocation of bus section and device ID

Secondary injection with test set type ......

Isolator auxiliary contacts (Isolator image)

Coupler breaker aux. contacts / Manual close

Integrated breaker failure protection

Breaker failure protection starting (external)

Check of input signals

Check of signalling circuits / alarms

Check of tripping circuits

Stability check

System time setting

Final check

If non ABB Power Automation Ltd test sets were used, note type, number, calibration date:




Date: Signature:

Client

Date: Signature:

General datas

Nominal voltage of the protected station ............... kV

Type of installation (Double busbar, 1½ system ...) ................................................................................... Air insulated (AIS) ................................................................................... Gas insulated (GIS) ...................................................................................

Software version ............................................................................................................................................................................................................................................................................................................................................

Used drawings ...................................................................................(Designation, no. and modification index) ...................................................................................

...................................................................................

...................................................................................

...................................................................................

Check of power supply

Type of battery grounding ...................................................................................(Minus grounded, floating, ...................................................................................symmetrically grounded at high impedance ...)

Measured voltages:

First battery: Second battery: not applicablePlus to minus ............... V Plus to minus ............... VPlus to ground ............... V Plus to ground ............... VGround to minus ............... V Ground to minus ............... V

Check of auxiliary contacts

Isolator end-position "OPEN" Isolator end-position "CLOSED"

Auxiliary contact must be closed

Auxiliary contact ideally closed

Auxiliary contact must be open

„Closed“ auxiliarycontact (N/O)

Isolation gap

„Open“ auxiliarycontact (N/C)

Condition of isolator switching sequence fulfilled: Yes No

Remarks:............................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................................




Date: Signature:

Client

Date: Signature:

Binary input/output module 500BIO01

Central unit, Slot ..........

Binary inputs Function/Remarks checked

OC01

OC02

OC03

OC04

OC05

1

2

3

45

67

8

9

1011

1213

14

15

1617

18

OC06

OC07

OC08

OC09

OC10

OC11

OC12

OC01 ..................................................................................................

OC02 ..................................................................................................

OC03 ..................................................................................................

OC04 ..................................................................................................

OC05 ..................................................................................................

OC06 ..................................................................................................

OC07 ..................................................................................................

OC08 ..................................................................................................

OC09 ..................................................................................................

OC10 ...................................................................................................

OC11 ..................................................................................................

OC12 ..................................................................................................

Tripping and signalling contacts

CR01

12345

76

CR05

8910

CR06

111213

CR07

1415161718

CR02CR03

CR08CR09

CR04

CR01 ..................................................................................................

CR02 ..................................................................................................

CR03 ..................................................................................................

CR04 ..................................................................................................

CR05 ..................................................................................................

CR06 ..................................................................................................

CR07 ..................................................................................................

CR08 ..................................................................................................

CR09 ..................................................................................................




Date: Signature:

Client

Date: Signature:

2nd Binary input/output module 500BIO01 (if equipped only)

Central unit, Slot ..........


OC01

OC02

OC03

OC04

OC05

1

2

3

45

67

8

9

1011

1213

14

15

1617

18

OC06

OC07

OC08

OC09

OC10

OC11

OC12

OC01 ..................................................................................................

OC02 ..................................................................................................

OC03 ..................................................................................................

OC04 ..................................................................................................

OC05 ..................................................................................................

OC06 ..................................................................................................

OC07 ..................................................................................................

OC08 ..................................................................................................

OC09 ..................................................................................................

OC10 ...................................................................................................

OC11 ..................................................................................................

OC12 ..................................................................................................

Signalling Contacts Function/Remarks checked

CR01

12345

76

CR05

8910

CR06

111213

CR07

1415161718

CR02CR03

CR08CR09

CR04

CR01 ..................................................................................................

CR02 ..................................................................................................

CR03 ..................................................................................................

CR04 ..................................................................................................

CR05 ..................................................................................................

CR06 ..................................................................................................

CR07 ..................................................................................................

CR08 ..................................................................................................

CR09 ..................................................................................................




Date: Signature:

Client

Date: Signature:

Bay unit 500BU02

Feeder ..................................


OC01

OC02

1 A

234

OC03

OC04

5

678

OC07

OC08

13

1415

OC05

OC06

9

101112

OC09

OC10

1 B

234

OC11

OC12

5

678

OC15

OC16

13

1415

OC13

OC14

9

101112

OC01 ..................................................................................................

OC02 ..................................................................................................

OC03 ..................................................................................................

OC04 ..................................................................................................

OC05 ..................................................................................................

OC06 ..................................................................................................

OC07 ..................................................................................................

OC08 ..................................................................................................

OC09 ..................................................................................................

OC10 ...................................................................................................

OC11 ..................................................................................................

OC12 ..................................................................................................

OC13 ..................................................................................................

OC14 ..................................................................................................

OC15 ..................................................................................................

OC16 ...................................................................................................




Date: Signature:

Client

Date: Signature:

Bay unit 500BU02

Feeder ..................................

Tripping and signalling contacts Function/Remarks checked

4

CR11

56789

CR12CR13

10

CR14

1112131415

CR15CR16

CR91 D23CR10

CR02

456

CR01

1 C23

CR03789CR04

CR05101112CR06

CR07131415CR08

CR01 ..................................................................................................

CR02 ..................................................................................................

CR03 ..................................................................................................

CR04 ..................................................................................................

CR05 ..................................................................................................

CR06 ..................................................................................................

CR07 ..................................................................................................

CR08 ..................................................................................................

CR09 ..................................................................................................

CR10 ..................................................................................................

CR11 ..................................................................................................

CR12 ..................................................................................................

CR13 ..................................................................................................

CR14 ..................................................................................................

CR15 ..................................................................................................

CR16 ..................................................................................................




Date: Signature:

Client

Date: Signature:

Secondary injection: Check of the input current transformers

Measurement of pick-up values IKmin

Setting: Ikmin L1, L2, L3 ............... A Ikmin N ............... A

Each current transformer has to be measured

Feeder Current trans-former ratio [A/A]

Injectionto bus

Nominal value [A] Measured Value [A]

[ABB No.] L1,L2,L3 L0 L1,L2,L3 L0 L1 L2 L3 L0

Remarks:




Date: Signature:

Client

Date: Signature:

Secondary injection: Check of the input voltage transformers

Feeder Voltage transformerratio [kV/V]

Voltage injected [V] LMI / HMI displayVoltage [kV]

[ABB No.] L1,L2,L3 L0 L1,L2,L3 L0 L1 L2 L3 L0

Remarks:




Date: Signature:

Client

Date: Signature:

Stability check with primary injection with load current

Bus / Bus section ...............

Feeder Primarycurrent [A]

LMI / HMI displayFeeder current [A]

LMI / HMI displayDifferential current [A]

[ABB No.] L1 L2 L3 L1 L2 L3 L0 L1 L2 L3 L0

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

..... -- -- ..... -- -- ..... ..... -- -- .....

open -- ..... -- -- ..... -- ..... -- ..... -- .....

on bus ..... -- -- ..... -- -- ..... ..... -- -- ..... .....

Remarks:

Notification Form for Errors in this Document

Dear User,

We are always endeavouring to improve the quality of out technical publicationsand would like to hear your suggestions and comments. Would you therefore pleasefill in this questionnaire and return it to the address given below.

ABB Power Automation LtdTechnical Publications Dept. NSV-6Haselstrasse 16 / 65/1CH-5401 BadenFax +41 56 205 28 00------------------------------------------------------------------------------------------------------------------

Concerns publication: 1MRB520259-Uen (REB 500 V5.0)

Have you discovered any mistakes in this publication? If so, please note here thepages, sections etc.

Do you find the publication readily understandable and logically structured? Can youmake any suggestions to improve it?

Is the information sufficient for the purpose of the publication? If not, what is missingand where should it be included?

Name Date

Company

Postal code Town Country

Notification Form for Equipment Faults and Problems

Dear User,

Should you be obliged to call on our repair service, we kindly as you to attach a noteto the unit describing the fault as precisely as possible. This will assist us to carry outthe repair swiftly and reliably and you will gain the benefit.Please attach a completed form to every unit and forward them to the address below.

ABB Power Automation LtdRepair CentreEingang West, Warenannahme Terminal CACH-5401 BadenSwitzerland

------------------------------------------------------------------------------------------------------------------

Equipment data:

Unit type:Serial No.: HE ..................................In operation since:

Reason for return: (tick where applicable)

Overfunction No function Outside tolerance Abnormal operating temperature Sporadic error Unit for checking

Remarks/Description of fault:

Customer: Date:

Address:

Please contact: Phone: Fax:

Notification Form for Software Errors and Problems

Dear User,

It is common experience that software does not always function as expected for allapplications. A precise description of the problem and observations will help us toimprove and maintain the software to your benefit. Please complete this form andsend it together with any supporting information or documents to the address below.

ABB Power Automation LtdSoftware Support Group NSTHaselstrasse 16/122CH-5401 BadenSwitzerland

---------------------------------------------------------------------------------------------------------------

Unit/ REB 500 SW version: MMC operator SW version: program (PC)

Problem: Program error (unit/system) Program error (MMC/PC) Manual error Suggestion for improvement other:

Can the error be reproduced at will? yes no

Particulars of hardware and software (system configuration, type of PC etc.):

Problem located? yes noSuggested changes enclosed? yes no

The following are enclosed (floppy with settings etc.):

Floppy Unit/system settings, file name: other:

Description of problem:

Customer: Date:

Address:

Please contact: Phone: Fax:

DESCRIPTION OF PROBLEM: (continuation)

___________________________________________________________________ACTION (internal use of ABB Power Automation Ltd, Dept. NST only)

Received by: Date:Answered by: Date:

Problem solved? yes no

Week Name Position Consequence------------------------------------------------------------------------------------------------------------------

IMPORTANT NOTICE!

The busbar protection REB 500 may only be installed, operatedand maintained by trained personnel.

Experience has shown that reliable operation of our products isassured, providing the information and recommendationscontained in these Operating Instructions are adhered to.

It is scarcely possible for the instructions to cover everyeventuality that can occur when using technical devices andsystems. We would therefore request the user to notify us di-rectly or our agent of any unusual observations or of instances,in which these instructions provide no or insufficient information.

In addition to these instructions, any applicable local regulationsand safety procedures must always be strictly observed bothwhen connecting up and commissioning this equipment.

Any work such as insertion or removal of soldered jumpers orsetting resistors, which may be necessary, may only beperformed by appropriately qualified personnel.

We expressly accept no responsibility for any direct damage,which may result from incorrect operation of this equipment,even if no reference is made to the particular situation in theOperating Instructions.

ABB Power AutomationABB Power Automation LtdHaselstrasse 16/122CH-5401 Baden/ SwitzerlandTelephone +41 56 205 77 44Telefax +41 56 205 55 77Home pagewww.abb.com/substationautomation

ABB Automation Products ABS-72171 VästeråsSwedenTelephone +46 21 32 13 00Telefax +46 21 14 69 18

ABB Transmit OyRelays and Network ControlPostfach 699FIN-65101 Vaasa, FinnlandTelephone +358 10 224 000Telefax +358 10 224 1094

ABB Power T&D Co.4300 Coral Ridge DriveCoral Springs, Fla. 33065USATelephone +1 954 752 6700 ext. 2461Telefax +1 954 345 5329

Printed in Switzerland (0011-0000-0)

www.abb.com/substationautomation

Documents

Reb5_E