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Substation Automation Products

Bay protection functions REB500Application Manual

Document ID: 1MRK 505 353-UENIssued: March 2016

Revision: AProduct version: 8.2

© Copyright 2016 ABB. All rights reserved

Copyright

This document and parts thereof must not be reproduced or copied without writtenpermission from ABB, and the contents thereof must not be imparted to a third par-ty, nor used for any unauthorized purpose.

The software and hardware described in this document is furnished under a licenseand may be used or disclosed only in accordance with the terms of such license.

Trademarks

ABB and Relion are registered trademarks of the ABB Group. All other brand orproduct names mentioned in this document may be trademarks or registered trade-marks of their respective holders.

Warranty

Please inquire about the terms of warranty from your nearest ABB representative.

ABB ABSubstation Automation ProductsSE-721 59 VästeråsSwedenTelephone: +46 (0) 21 32 50 00Facsimile: +46 (0) 21 14 69 18http://www.abb.com/substationautomation

http://www.abb.com/substationautomation

Disclaimer

The data, examples and diagrams in this manual are included solely for the conceptor product description and are not to be deemed as a statement of guaranteed prop-erties. All persons responsible for applying the equipment addressed in this manualmust satisfy themselves that each intended application is suitable and acceptable,including that any applicable safety or other operational requirements are compliedwith. In particular, any risks in applications where a system failure and /or productfailure would create a risk for harm to property or persons (including but not lim-ited to personal injuries or death) shall be the sole responsibility of the person orentity applying the equipment, and those so responsible are hereby requested to en-sure that all measures are taken to exclude or mitigate such risks.

This document has been carefully checked by ABB but deviations cannot be com-pletely ruled out. In case any errors are detected, the reader is kindly requested tonotify the manufacturer. Other than under explicit contractual commitments, in noevent shall ABB be responsible or liable for any loss or damage resulting from theuse of this manual or the application of the equipment.

Conformity

This product complies with the directive of the Council of the European Communi-ties on the approximation of the laws of the Member States relating to electromag-netic compatibility (EMC Directive 2004/108/EC) and concerning electricalequipment for use within specified voltage limits (Low-voltage directive2006/95/EC). This conformity is the result of tests conducted by ABB in accord-ance with the product standards EN 50263 and EN 60255-26 for the EMC di-rective, and with the product standards EN 60255-1 and EN 60255-27 for the lowvoltage directive. The product is designed in accordance with the internationalstandards of the IEC 60255 series.

Safety information

Dangerous voltages can occur on the connectors, even though theauxiliary voltage has been disconnected.

Non-observance can result in death, personal injury or substantialproperty damage.

Only a competent electrician is allowed to carry out the electricalinstallation.

National and local electrical safety regulations must always be fol-lowed.

The frame of the IED has to be carefully earthed.

Whenever changes are made in the IED, measures should be takento avoid inadvertent tripping.

The IED contains components which are sensitive to electrostaticdischarge. Unnecessary touching of electronic components musttherefore be avoided.

Table of contents

Application Manual 1Bay protection functions REB500

Table of contents

Section 1 Introduction ................................................................. 31.2 This manual .................................................................................... 31.3 Intended audience .......................................................................... 31.4 Product documentation ................................................................... 31.5 Symbols and conventions ............................................................... 41.5.1 Symbols ..................................................................................... 41.5.2 Document conventions ............................................................... 4

Section 2 Overview .................................................................... 62.1 Functionalities ................................................................................. 62.2 Structure of protection function software .......................................... 62.2.1 Functional diagram of bay protection REB500 ............................ 72.2.2 Label number guide for Figure 1................................................. 82.3 Signals............................................................................................ 92.3.1 Bay / Station Protectionà function overlapping signals.............. 92.3.2 Bay protectionà function-specific signals ................................ 11

Section 3 Configuring bay protection using HMI500 .................... 183.1 Integration of bay protection .......................................................... 183.2 Configuring the bay protection using HMI500 ................................ 193.3 Select Protection Function ............................................................ 193.4 Binary signal configuration ............................................................ 233.4.2 Configuring binary output signals ............................................. 293.4.3 Recording a binary signal as an event ...................................... 323.4.4 Disturbance recording of a binary signal ................................... 323.5 Protection function settings ........................................................... 32

Section 4 System functions ....................................................... 334.1 BP Function Monitoring ................................................................. 334.2 BP Licenses .................................................................................. 344.3 CT grounding ................................................................................ 34

Section 5 Bay protection functions ............................................ 355.1 Application / Technical details ....................................................... 355.2 Technical additions ....................................................................... 36

Table of contents

2 Application ManualBay protection functions REB500

5.2.1 Voltage transformers for bay protection .....................................36

Section 6 BP-Additions to base documentation .......................... 386.1 Technical Data ...............................................................................386.2 Operation and maintenance ...........................................................466.2.1 Maintenance of bay protection functions....................................466.2.2 Protection blocking....................................................................466.2.3 Protection tripping .....................................................................466.3 Commissioning ..............................................................................486.3.1 Regulations...............................................................................486.3.2 Additional checks for bay protection REB500 ............................486.4 Communication ..............................................................................51

1MRK 505 353-UEN Section 1Introduction


Section 1 Introduction

1.2 This manual

The manual contains application descriptions, setting guidelines and technical datafor the bay protection functions. It is complementary to the basic Application Man-ual of REB500.

The manual can be used to find out when and for what purpose a typical protectionfunction can be used. The manual can also be used when calculating settings.

1.3 Intended audience

This manual addresses the protection and control engineer responsible for plan-ning, pre-engineering and engineering.

The protection and control engineer must be experienced in electrical power engi-neering and have knowledge of related technology, such as protection schemes andcommunication principles.

1.4 Product documentation

Manual Document numberProduct Guide 1MRK 505 352-BEN

Application Manual 1MRK 505 349-UEN

Technical Manual 1MRK 505 350-UEN

Operation Manual 1MRK 500 124-UEN

Commissioning Manual 1MRK 505 351-UEN

Application ManualBay protection Functions

1MRK 505 353-UEN

Cyber Security Guideline 1MRK 511 373-UEN

Communication Protocol ManualIEC 61850

1MRK 511 370-UEN

Communication Protocol Manual,IEC 60870-5-103

1MRK 511 371-UEN

Section 1 1MRK 505 353-UENIntroduction


1.5 Symbols and conventions

1.5.1 Symbols

The electrical warning icon indicates the presence of a hazard whichcould result in electrical shock.

The warning icon indicates the presence of a hazard which could re-sult in personal injury.

The caution icon indicates important information or warning relatedto the concept discussed in the text. It might indicate the presence ofa hazard which could result in corruption of software or damage toequipment or property.

The information icon alerts the reader of important facts and condi-tions.

The tip icon indicates advice on, for example, how to design yourproject or how to use a certain function.

Although warning hazards are related to personal injury, it is necessary to under-stand that under certain operational conditions, operation of damaged equipmentmay result in degraded process performance leading to personal injury or death.Therefore, comply fully with all warning and caution notices.

1.5.2 Document conventions

A particular convention may not be used in this manual.

• Abbreviations and acronyms in this manual are spelled out in the glossary. Theglossary also contains definitions of important terms.

• Push button navigation in the LHMI menu structure is presented by using thepush button icons, e.g.:

To navigate the options, use and .

1MRK 505 353-UEN Section 1Introduction


• HMI menu paths are presented in bold, e.g.:Select Main menu/Settings.

• LHMI messages are shown in Courier font, e.g.:To save the changes in non-volatile memory, select Yes and ….

• Parameter names are shown in italics, e.g.:The function can be enabled and disabled with the Operation setting.

• The * character after an input or output signal name in the function blocksymbol given for a function indicates that the signal must be connected to an-other function block in the application configuration to achieve a valid applica-tion configuration.

Section 2 1MRK 505 353-UENOverview


Section 2 Overview

In addition to the station protection (SP) the system includes bay protection func-tions (BP) applicable for HV and EHV networks. Depending on the requirementssingle functions up to system specific line protection arrangements can be config-ured.

Adding the BP arrangement is made under the “Configurator mode” of HMI500.

2.1 Functionalities

Table 1 Available Bay protection functionsFunction REB5000 IEEE /

ANSI No.IEC61850

Base L-V2

Logic LOGIC - - x x

Delay / integrator DELAY - - x x

Distance protection DIST 21 PDIS/PSCH - x

Definite time over and undercurrent protection OCDT 51 PTOC - x

Inverse time overcurrent protection OCINV 51 PTOC - x

Directional overcurrent definite time protection DIROCDT 67 PTOC - x

Directional overcurrent inverse time protection DIROCINV 67 PTOC - x

Inverse time earthfault overcurrent protection I0INV 51N PTOC - x

Peak value over and undercurrent protection OCINST 50 PTOC - x

Definite time over and undervoltage protection OVDT 59/27 PTOV - x

Three phase current plausibility CHKI3PH 46 PTOC - x

Three phase voltage plausibility CHKU3PH 47 PTOV - x

More than one instance of functions is available and may be configured (e.g. twoinstances of the OCDT function)

2.2 Structure of protection function software

Figure 1 and the subsequent tables give an overview of the structure of the stationand bay protection functions in a bay unit. These functions are accessed throughso-called BP-input (Bi) and BP output blocks (Bo) which can accommodate up to20 input and 120 output signals respectively.

1MRK 505 353-UEN Section 2Overview


It is to be noted that all signals that are to be mapped to the binary output contacts,substation automation systems SAS (e.g. IEC 61850 bus) or LEDs first have to berouted via the BP output block (Bo).

The following diagram gives an overview of the protection function und hardwareblocks of a RE500 bay unit including the possible signal assignments. Table 2 toTable 4 provide the detailed description of the labeled items.

2.2.1 Functional diagram of bay protection REB500

For the purposes of illustration, the configuration steps describedunder Section 3 refer to the functional diagram Figure 1 below andthe herein included label numbers.

Figure 1 Structure and assignment of station and bay protection functions



2.2.2 Label number guide for Figure 1

Table 2 Explanations to inputs / outputsItem No. Name Definition Remark1 OC input Optocoupler input of bay unit 33 binary inputs per bay unit2 CR output Relay (contact) output of bay

unit19 binary outputs per bay unit

3 U, I input Analog input of bay unit Assignment to SP functions is fixed.Assignment to BP functions is partlyconfigurable.

4 BP input Logical input of BP part 20 logical inputs per bay unit5 BP output Logical output of BP part 120 logical outputs per bay unit

Table 3 Explanations to protection function partLabel No. Name Definition Remark6 SP Station protection part Contains station protection functions

SP function Station protection function Available functionse.g. BBP, BFP, EFP, ..

7 BP Bay protection part Contains bay protection functionsBP function Bay protection function Available functions

e.g. DIST, OCDT, ..

Table 4 Explanations to signal connectionsLabel No. Definition Remark8 OC input assigned to SP function Assignment via software HMI500

e.g. 13710_Start BFP_L1_19 SP function assigned to CR output Assignment via software HMI500

e.g. 23105_BFP TRIP10 OC input assigned to BP input Assignment via software HMI500

e.g. 111205_DIST Ext. Block Dist.11 BP input assigned to BP function Assignment via software HMI500

e.g. DIST: Ext Blk Dist12 BP function assigned to BP output Assignment via software HMI500

e.g. DIST: Com Send13 BP-output assigned to CR output Assignment via software HMI500

e.g. 211880_ DIST Com14 BP-output assigned to SP function Assignment via software HMI500

e.g. DIST: Trip_DIST à 13785_BP StartBFP L1L2L3

15 SP-function assigned to BP input Assignment via software HMI50016 OC-input assigned to SP function and BP

inputAssignment via software HMI500e.g. 11530/ 118515_Q0 Open and CBOPEN

17 SP function and BP output assigned to CRoutput

Assignment via software HMI500e.g. 21110/ 220815_TRIP

18 Internal connections between BP-functions Assignment via software HMI50019 Internal connections between SP-functions Automatic assignment done by REB500

ITT-system (ITT = intertripping)



2.3 Signals

2.3.1 Bay / Station Protection à function overlapping signals

2.3.1.1 Signal designations

The BP/ SP function overlapping (general) signals correspond to the signal num-bers nomenclature of the station protection system (for details see Technical Man-ual REB500)

Example: 19205_Block BP (5 digit signal number)

2.3.1.2 Outputs generated by BP and used as SP inputs (default signals)

Table 5 BU_ BP outputs to SP inputs (default signals)Signal Description11120_BP External TRIP This is the tripping signal generated by bay protection of

REB500. It trips faults on a line with the aid of the REB500tripping contact. Tripping thus takes account of the busbarconfiguration at the time. The signal is activated by the bayprotection directly and does not therefore appear as binaryinput signal.

11125_BP External TRIP BB zone This is a tripping signal generated by the bay protection ofREB500 which is used to trip the entire bus zone to which thefbay is connected. The tripping command is applied to all thebay units of the bus zone and sections of busbars intercon-nected by an isolator (intertripping).

13210_BP Block BFP This signal is directly activated by the bay protection anddoesn’t therefore appear as a binary input signal. The opera-tion of the breaker failure protection of the correspondingfeeder is blocked. When the blocking signal is cancelled andproviding a starting signal is present and current is flowing, thetimers start again at t = 0.

13610_BP Trip transfer Reserved for the special application “trip transfer”.This signal is directly activated by the bay protection unit anddoes not therefore appear as a binary input signal.

13761_BP Start BFP L1L2L3_5 This signal is functionally identical to signal "13760_Start BFPL1L2L3_5", but it is directly activated by the bay protection anddoes not therefore appear as a binary input signal.

13770..13780_BP Start BFP Lp Breaker failure protection with phase-selective starting (p = 1,2 or 3). The breaker failure protection timer starts when thissignal is activated by BP functions and the BFP measures acurrent in the corresponding phase. This signal is directlyactivated by the bay protection and does not therefore appearas a binary input signal.

13785_BP Start BFP L1L2L3 Breaker failure protection with three-phase starting. Thebreaker failure protection timer starts when this signal is acti-vated and the BFP measures a current in any phase.This signal is directly activated by the bay protection and doesnot therefore appear as a binary input signal.



Signal Description13790_BP External start BFP Breaker failure protection with three-phase starting. The

breaker failure protection timer starts when this signal is acti-vated regardless of the current measurement.This signal is directly activated by the bay protection and doesnot therefore appear as a binary input signal.

13797_BP Start BFP L0 Breaker failure protection with L0 - starting. The breaker failureprotection timer starts when this signal is activated by BPfunctions and the BFP measures a current in the neutral sys-tem. This signal is directly activated by the bay protection anddoes not therefore appear as a binary input signal.

16760_BP Global Start DR Starts those disturbance recorders in the bay units that areconfigured. The signal ‘Central start DR’ in the bay units mustbe configured. This signal is directly activated by the BP unitand does not therefore appear as a binary input signal.

2.3.1.3 General inputs to BP

Table 6 BU_ Inputs to BPSignal Description19205_Block BP The BP output signals of the respective bay unit are blocked.

(Internal processing of the functions continues and thereforemeasurements and signals continue to be displayed on thelocal HMI.)

19600_Activation BP ParSet_1 The protection functions and settings assigned to parameterset 1 are active. They remain active after the signal has beenreset.




Table 7 CU_ Inputs to BPSignal Description39205_Block BP The bay protection output signals are blocked throughout the

system (internal processing of the functions continues andtherefore measurements and signals continue to be displayedon the local HMI).



2.3.1.5 General outputs from BP

Table 8 BU_ Output signals from BPSignal Description29405_BP blocked Signals that the outputs of the bay protection functions are

blocked (either the bay concerned or throughout the system).29410_BP partial blocked Signals certain bay protection functions are blocked

(Signal must be set explicitly in the bay protection).29600 ParaSet_1 active Signals that parameter set 1 is active (activated via the station

bus or an input signal).29605 ParaSet_2 active Signals that parameter set 2 is active (activated via the station



bus or an input signal).

Table 9 CU_ Output signals from BPSignal Description49405_BP blocked Signals that the outputs of the bay protection functions are

blocked (either individual bays or throughout the system).49410_BP partial blocked Signals that certain bay protection output signals in specific

bays or throughout the entire system are blocked (Must beconfigured together with the corresponding BU output signal29410_BP partial blocked).

2.3.2 Bay protection à function-specific signals

2.3.2.1 Signal designations of binary inputs and outputs

The signal range of REB500 is expanded for the bay protection functions. The BPfunction-specific signal can be identified by a 6 digit signal number

Example:

Signal 211105_DIST_Trip CB L1

Table 10 Signal numbers nomenclature211105 DIST Trip CB L1

6 Digit signal number Protection function Signal designation



Table 11 Signal numbers nomenclatureDigit 1Category

Digit 2,3Protectionfunction

Digit 4Signal function

Digit 5,6Sequencenumber

1 BU_in 11 DIST 1 TRIP 05

2 BU_out 12 OCDT 2 Block command 10

3 CU_in 13 OCINV 3 Tripping signal 15

4 CU_out 14 DIROCDT 4 Blocking signal 20

5 System 15 DIROCINV 5 Bus image etc.

16 OVTD 6 Control

21 I0INV 7 Start

24 CHKI3PH 8 General alarm

25 CHKU3PH

26 OCINST

2.3.2.2 Signal designations of BP internal signals

Each BP function provides a set of internal input and output signals. They can bemapped to binary inputs (optocoupler) and outputs (contacts) of the bay unit by us-ing the corresponding binary inputs and output signals.

Example:

BP internal Signal Designation of binary input signalTrip CB L1 211105_DIST TRIP CB L1

2.3.2.3 Binary input signals of BP

Table 12 BU_ Logic input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 122205_LOGIC Block Input for blocking LOGIC functionBinary Input 1 122805_LOGIC Binary Input 1 Logic input 1Binary Input 2 122810_LOGIC Binary Input 2 Logic input 2Binary Input 3 122815_LOGIC Binary Input 3 Logic input 3Binary Input 4 122820_LOGIC Binary Input 4 Logic input 4

Table 13 BU_ Delay input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 123205_DELAY Block Input for blocking of DELAY functionBinary Input 123805_DELAY Binary Input Input to be delayed



Table 14 BU_ DIST input signalsBP int. Signal Designation of binary input sig. DescriptionExt Blk Dist 111205_DIST Ext. Block Dist. Input for disabling the distance protection func-

tion.Ext Blk PSB 111215_DIST Ext. Blk. PSB Input for blocking the power-swing functionExt Blk O/C 111220_DIST Ext. Block O/C Input the backup overcurrent functionExtBlkSOTF 111225_DIST Ext. Block SOTF Input for blocking the tripping condition for the

switch-onto-fault logicExtBlkHF 111230_DIST Ext. Block HF Input for blocking a received PLC signal (con-

trolled, for example, by a sensitive E/F schemeusing the same PLC channel

ExtBlock Z1 111235_DIST Ext. Block Z1 Input for blocking measurement in the first zoneManual close 111505_DIST Manual Close Circuit breaker manual close commandIsol Open 111510_DIST Isolator Open Isolator open signal for activating the ‘short-zone’

logic and protection (T section in 1½ breakerschemes)

ChgMeasDir 111605_DIST Change Meas.Dir.

Input for changing the direction of measurement

DeadLine 111805_DIST Deadline Line de-energized signal (auxiliary contact on thecircuit-breaker when the VTs are on the busbar)

ZExtension 111810_DIST Zextension External zone extension control signalZone extension

Com Rec 111815_DIST Com Rec Input for PLC signal from the remote stationCom Fail 111820_DIST Com Fail Input for PLC failure signal

Table 15 BU_ OCDT input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 112205_OCDT Block Input for blocking OCDT

Table 16 BU_ OCINV input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 113205_OCINV Block Input for blocking of OCINV

Table 17 BU_ DIROCDT input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 114205_DIROCDT Block Input for Blocking of DIROCDTReceive 114805_DIROCDT Receive PLC receive signal

Table 18 BU_ DIROCINV input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 115205_DIROCINV Block Input for blocking of DIROCINVReceive 115805_DIROCINV Receive PLC receive signal



Table 19 BU_ I0INV input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 121205_I0INV Block Input for blocking of I0INV

Table 20 BU_ OCINST input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 126205_OCINST Block Input for blocking of OCINST

Table 21 BU_ OVDT input signalsBP int. Signal Designation of binary input sig. Description

Block 116205_OVDT Block Input for blocking of OVTD

Table 22 BU_CHKI3PH input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 124205_CHKI3PH Block Input for blocking of CHKI3PH

Table 23 BU_ CHKU3PH input signalsBP int. Signal Designation of binary input sig. DescriptionBlock 125205_CHKU3PH Block Input for blocking of CHKU3PH

2.3.2.4 Binary output signals of BP

Table 24 BU_ LOGIC output signalsBP int. Signal Designation of binary output sig. DescriptionBinary output 222805_LOGIC Binary Output Logic signal (output from logic)Binary output 222810_LOGIC BINARY OUT-

PUTTrip signal (output from trip logic)

Table 25 BU_ DELAY output signalsBP int. Signal Designation of binary output sig. Description

Trip 223105_DELAY TRIP Trip signalStart 223705_DELAY Start Start signal

Table 26 BU_ DIST output signalsBP int. Signal Designation of binary output sig. DescriptionTrip CB L1 211105_DIST TRIP CB L1 Circuit-breaker L1 phase trip

This signal is disabled while a blocking signal isbeing applied with the exception of a trip by thebackup over-current protection.



BP int. Signal Designation of binary output sig. DescriptionTrip CB L2 211110_DIST TRIP CB L2 Circuit-breaker L2 phase trip

This signal is disabled while a blocking signal isbeing applied with the exception of a trip by thebackup over-current protection.

Trip CB L3 211115_DIST TRIP CB L3 Circuit-breaker L3 phase tripThis signal is disabled while a blocking signal isbeing applied with the exception of a trip by thebackup over-current protection.

Trip CB 211305_DIST TRIP CB General circuit-breaker tripping signal. Thissignal is disabled while a blocking signal is beingapplied with the exception of a trip by the backupovercurrent protection.

Trip L1L2L3Trip L1L2L3Aux

211310_DIST Trip L1L2L3211315_DIST Trip L1L2L3 Aux

General tripping signal. This signal is not disa-bled while a blocking signal is being applied.

Trip CB 3P 211320_DIST Trip CB 3ph Three-phase trip signal. This signal is disabledwhile a blocking signal is being applied with theexception of a trip by the backup overcurrentprotection.

Trip CB 1P 211325_DIST Trip CB 1ph Single-phase trip signal. This signal is disabledwhile a blocking signal is being applied with theexception of a trip by the backup overcurrentprotection.

Trip O/C 211330_DIST Trip O/C Backup overcurrent trip signal.Trip SOTF 211335_DIST Trip SOTF Switch-onto-fault trip signal.Trip Com 211340_DIST Trip Com Signal for tripping either enabled by the receipt

of a permissive signal or the non-receipt of ablocking signal. (This signal is disabled while ablocking signal is being applied.)

Trip Stub 211345_DIST Trip Stub 'Short-zone’ protection trip signal.Dist Blocked 211405_DIST Blocked Signal indicating that the distance protection is

blocked.DelDistBlk 211410_DIST Del Blocked Signal delayed by 12 s indicating that the dis-

tance protection is blocked.StartL1+L2+L3

211705_DIST Start L1+L2+L3 General distance protection starting signal (ORlogic for all starting signals excepting ‘weakinfeed').

Start L1L2L3Start L1L2L3Aux

211710_DIST Start L1L2L3211715_DIST Start L1L2L3 Aux

General distance protection starting signal (ORlogic for all starting signals including ‘weak in-feed').

Start L1Start L1 Aux

211720_DIST Start L1211725_DIST Start L1 Aux

Distance protection L1 phase starting signal(including ‘weak infeed').








211750_DIST Start E211755_DIST Start E Aux

Distance protection E/F starting signal (U0 or I0).Only generated together with a phase starter.

Start I0 211760_DIST Start I0 Neutral current starting signal (I0).Start U0 211765_DIST Start U0 Neutral voltage starting signal (U0).Start OC 211770_DIST Start O/C Overcurrent starting signal.Start SOFT 211780_DIST Start SOTF Enabling signal for the switch-onto-fault protec-

tion.



BP int. Signal Designation of binary output sig. DescriptionStart O/C 211785_DIST Start OC Backup overcurrent start signal.Start UZ 211790_DIST Start UZ Underimpedance starting signal.Start 1ph 211805_DIST Start 1ph Indicates that the distance protection was started

by a single phase.Delay >= 2 211810_DIST Delay >= 2 Signal for starting in Zone 2 or higher.Delay 1 211815_DIST Delay 1 Signal for starting in Zone 1.Delay 2 211820_DIST Delay 2 Signal for starting in Zone 2.Delay 3 211825_DIST Delay 3 Signal for starting in Zone 3.Delay 4 211830_DIST Delay 4 Signal for starting in Zone 4 (excepting when

Zone 4 is being used as an overreaching zone).Delay Def 211835_DIST Delay Def Signal for starting in the final zone.Meas Main 211840_DIST Meas Main Measurement by the distance function (Zones 1,

2, 3, 4 or the final zone).MeasOreach

211845_DIST Meas Oreach Measurement in the distance protection over-reach zone.

Meas Fward 211850_DIST Meas Fward Measurement by the distance protection in theforwards direction.

Meas Bward 211855_DIST Meas Bward Measurement by the distance protection in thereverse direction (reverse zone).

Weak Infeed 211860_DIST Weak Infeed Tripping by the ‘weak infeed’ function.Power Swing 211865_DIST Power Swing Power-swing blocking function picked up.VTSup 211870_DIST VT Sup VT supervision picked up.VTSup Delay 211875_DIST VT Sup Delay Delayed operation of the VT supervision after

12 s.Com Send 211880_DIST Com Send Signal generated when a transfer trip signal is

transmitted.Com Boost 211885_DIST Com Boost Signal for boosting PLC transmitting power.Freq dev 211890_DIST Freq Dev Signal indicating a deviation of the memory

voltage frequency.

Table 27 BU_ OCDT output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 212105_OCDT TRIP Trip signalStart 212705_OCDT Start Start signal

Table 28 BU_ OCINV output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 213105_OCINV TRIP Trip signalStart 213705_OCINV Start Start signal

Table 29 BU_ DIROCDT output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 214105_DIROCDT TRIP Trip signal.Start 214705_DIROCDT Start Start signal.Start L1 214710_DIROCDT Start L1 L1 phase start signal



Start L2 214715_DIROCDT Start L2 L2 phase start signalStart L3 214720_DIROCDT Start L3 L3 phase start signalMeasFwd 214805_DIROCDT MeasFwd Signals measurement in the forwards direction.MeasBwd 214810_DIROCDT MeasBwd Signals measurement in the backwards direc-

tion.

Table 30 BU_ DIROCINV output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 215305_DIROCINV TRIP Trip signal.Start 215705_DIROCINV Start Start signal.Start L1 215710_DIROCINV Start L1 L1 phase start signalStart L2 215715_DIROCINV Start L2 L2 phase start signalStart L3 215720_DIROCINV Start L3 L3 phase start signalMeasFwd 215805_DIROCINV MeasFwd Signals measurement in the forwards direction.MeasBwd 215810_DIROCINV MeasBwd Signals measurement in the backwards direc-

tion.

Table 31 BU_ I0INV output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 221105_I0INV TRIP Trip signalStart 221705_I0INV Start Start signal

Table 32 BU_ OCINST output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 226105_OCINST TRIP Trip signalStart 226705_OCINST Start Start signal

Table 33 BU_ OVDT output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 216105_OVDT TRIP Trip signalStart 216705_OVDT Start Start signal

Table 34 BU_ CHKI3PH output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 224605_CHKI3PH Picked Up Trip signal

Table 35 BU_ CHKU3PH output signalsBP int. Signal Designation of binary output sig. DescriptionTrip 225605_CHKU3PH Picked Up Trip signal

Section 3 1MRK 505 353-UENConfiguring bay protection using HMI500


Section 3 Configuring bay protection using HMI500

3.1 Integration of bay protection

The REB500 bay models include no bay protection functionality. The integrationof the bay protection (variant V-L2) takes place under the setfile engineering dur-ing the “Import a Bay Model” process.

The dialogue “Bay model import options” enables the selection of the BP variantV-L2. After pressing the OK button, the respective bay is imported to the single-line diagram and the selected BP variant (comprising the “V-L2 set” of BP func-tions) is available for further configuration.

Figure 2 Selection the import option “Bay protection and “Variant””

For detailed information about the setfile engineering refer the REB500 Engineer-ing Manual Section “single-line diagram”

The setfile engineering and the integration of the Bay protection re-quires that the HMI500 is started under der “Configurator Mode”.After that, the configuration details can also be adjusted under the“Operator Mode”.

1MRK 505 353-UEN Section 3 Configuring bay protection using HMI500


3.2 Configuring the bay protection using HMI500

To configure and set the bay protection function, open the HMI500 menu “Set-tings” and select the menu item “Bay protection”.

Figure 3 Settings / Bay protection ConfigurationTable 36 “Bay protection – Configuration” - buttons

Button FunctionContinue Opens the dialogue “Select Protection Function” of a selected bay and

thus the BP configuration.Instead of “Continue” button, simply double click a unit line

Copy Copies the BP configuration of a selected bayPaste Pastes the copied BP configuration to a selected bayDelete configuration Delete the BP configuration of the selected bay

3.3 Select Protection Function

This dialog is divided into the following parts:

The protection functions available for configuration are listed on the left (in theform of buttons). Its content is determined by the already selected Bay protectionvariant (see Section 3.2).

The protection functions used for configuration are listed on the right. The first isalways the binary output function “BP output” (see Figure 4).



Figure 4 Select Protection Functions

Table 37 Select Protection Function – used BP FunctionsMenu item DescriptionNo. Unique instance number of the BP functionFunc. Symbol representing the BP function of the instanceDescription User specific description of the BP function of the instanceP1..P4 Parameter set in which the protection function occurs. Switching between

parameter sets is accomplished using the binary input signals 19600_x,19605_x, 19610_x and 19615_xx = “Activation BP ParSet 1..4”

Copy of Instance No. of the original function, where the instance is a copy of a func-tion that already exists.

If the number of function instances exceeds the size of the display area, a scroll barautomatically appears on the right. The maximum number of instances per bay unitis limited to 128.

There are a number of tabs, which can be selected in this part of the dialog. Thefirst tab (ParSet 1..4) lists all the functions. It has to be selected to change functionsand determine the instances where they occur. The tabs ParSet 1 to ParSet 4 listthe functions configured for a particular parameter set and are merely for infor-mation.

Creating instances of protection functions

An instance of a protection function is created by selecting it in the list on the leftof the dialog using the left mouse button and while keeping the button depresseddragging it onto the area of the first tab (ParSet 1..4) (drag and drop). It is not pos-sible to ‘drop’ the function while the symbol is being shown. The instance of



the protection function is created when the mouse cursor changes to an arrow andthe mouse button is released.

Assigning protection functions to parameter sets

Every instance of a protection function can be assigned to a particular parameterset. The REB500 runs the protection functions in the currently selected parameterset. The active parameter set is changed by setting the appropriate binary input onthe bay unit.

Figure 5 Parameter set assignment

To assign the instance of a protection function to a parameter set, simply check thecorresponding box using the left mouse button.

Using the context menu

To open the context menu for a particular protection function, first select the func-tion by clicking the left mouse button on its symbol and then clicking the rightmouse button.

Figure 6 Content menu

Table 38 Content menu dialoguesMenu item DescriptionCopy Creates a copy of the protection function according to the following rules:

• A copy cannot be in the same parameter set as the original.

• The input signals of a copy are the same as those of the original andcannot be changed.

• Only defined parameters of a copy can be configured. All other param-eters are taken from the original.



Menu item DescriptionDelete The instance of the specific protection function is deleted together with all the

settings that the user has made up to that point.If the function being deleted has connections to other protection functions, anerror message appears instructing you to first delete the connections.

Thus an instance can only be deleted after all its interconnections have beendeleted.

Properties This opens a dialog with all the function’s settings. Double clicking on thefunction’s symbol opens the same dialog.

Status indicator

On the left of each instance number and function symbol there is a status indicatorwhich signals the validity of the parameters entered.

Figure 7 Status indication of BP Function

Green indicates that the configuration is correct and valid while red indicates thatthe setting procedure has not been completed. This generally means in the case of asingle-phase function that an analog channel has not yet been assigned to it.

The “Bay protection” dialog cannot be closed by clicking on “OK” until all the sta-tus indicators are green.

Statistical evaluation

Double clicking with the right mouse button with the cursor in the dialog below thearea of the tabs opens a window with statistics and status information on the bayprotection functions.

Figure 8 Area below tabs – sensitive for selection of statistical evaluation

The version number of the bay protection configuration module is shown in thebottom left-hand corner.



Figure 9 Status indication of BP Function

Table 39 Status indication of BP Function – ModeDialogue tem DescriptionConfiguration The dialog is in the protection function configuration or setting mode.

Measurements The dialog was started in the measurement display mode.

Test Not implemented in this version.

Read- Write The user can edit and save settings.

Read- only The user cannot edit settings.

Table 40 Status indication of BP Function – StatisticsDialogue item DescriptionConfigured functions Number of instances created by the user for this bay unit. The maximum

number is 128.Available parame-ters

The number of memory locations available for protection function settingsin the entire system.

Used parameters Number of protection function settings used by the present bay unit.

3.4 Binary signal configuration

3.4.1.1 Configuring binary input signals

Each Bay protection function has a defined number of binary inputs. These are de-scribed for each of the protection functions in Section 2.3.2.3. .



In the dialogs for setting protection functions, a binary input is described in plaintext and has a button for configuration.

Figure 10 Setting binary input signal – e.g. OCDT Blocking input

The following signals can be assigned to the binary inputs of eachBP function:

BP internal

• outputs from an another BP function (see 3.4.1.2)• General inputs to BP (see 2.3.1.3)• Signal status “Always FALSE” or “Always TRUE”

BP external (see 3.4.1.4)

• Binary input signals (from optocoupler inputs)• Predefined outputs of a station protection function



3.4.1.3 Assignment of ‘BP internal’ input signals

Click the left mouse button on the status button of the desired signal to open the di-alog “Select Binary Input” for configuring the status of the particular binary inputsignal.

The dialog has two tabs, the first of which (“TRUE / FALSE”) provides facility forsetting the input status to “Always True”, OR “Always False”. This is a permanentassignment, without the involvement of an output signal of another function.

Figure 11 Configuring binary inputs (TRUE / FALSE)

The second tab “Output from Function” enables the output of an existing instanceof a protection function to be connected to the particular signal input.

The “Output from Function” tab lists all the protection function instances set forthe particular bay unit together with the unique number of the instance. Upon se-lecting a protection function in the list on the left by clicking the left mouse buttonon it, its binary output signals appear on the right of the dialog.



Figure 12 Configuring binary inputs (Output from other BP function)

Table 41 “Output from Function”- dialogue / Column designationsDialogue tem DescriptionChannel Unique No. of the output signal

Inv Check this box to invert the signal

Signal text Output signal name

Location of ‘BP internal’ input signals within the BP function dia-gram see Figure 1, Label No. 18.

3.4.1.4 Assignment ‘BP external’ input signals

The system automatically creates an instance “BP Binary Input”. It thus alwaysheads the list of instances.

If you select “BP Binary Input”, the right-hand half of the dialog presents two tabs“Default” and “General purpose”.



Default

The “Default” tab lists station protection default outputs (see Figure 13). Any bina-ry input of a BP function can be linked to these to enable the exchange of signalsbetween station protection and the bay protection sections (e.g. signal21105_External TRIP).

Figure 13 Configuring binary inputs (“Default” à Output from SP function)

Location of input signals from ‘SP function’within the BP func-tion diagram see Figure 1, Label No. 15.

General Purpose

The “General Purpose” tab provides facility for defining up to 20 user signals. Tothis end, select a signal number with the left mouse button. A text field appears inwhich the user can write a signal name (see Figure 14).

The signal name entered must conform to REB500 signal conventions (see Section2.3.2.1). The Section 2.3.2.3 provides a list of all signals available for “GeneralPurpose” inputs.



Example:

Signal name under the BP function Designation of binary input signals to be entered under“General Purpose”

Ext Blk Dist 111205_DIST Ext. Block Dist.

Figure 14 Configuring binary inputs (General purpose)

Location of ‘BP internal’ input signals within the BP function dia-gram see Figure 1, Label No. 11.

Once defined, signals can be assigned to an optocoupler input by selecting themenu “Configuration/ Binary module/ Inputs”.

Location of ‘Binary module’ input signals within the BP functiondiagram see Figure 1, Label No. 10.



3.4.2 Configuring binary output signals

Each REB500 bay protection function has a defined number of binary output sig-nals. These are described for each of the protection functions in Section 2.3.2.4. Inthe dialogs for setting protection functions, a binary output signal is described inplain text and has a field, which lists the input signals assigned to the respectiveoutput.

Figure 15 BP output signal assignment

The list shows the input signals assigned to the respective output. For each signalin the list, the instance number and an abbreviation of the function are given.

Table 42 BP output signal assignmentExample Description09 Instance of BP functionOR Symbol representing the BP function of the instanceBinary Inp 2 Binary input 2 of OR function

Output signals are assigned when configuring either the binary out-put function (see Section 3.4.2.1) or bay protection input signalfunction (see Section 3.4.1.1).

3.4.2.1 Exception: Binary output function

The binary output function has to be included in all sets of parameters and that iswhy the function is automatically selected for all of them and the setting cannot bechanged by the user.

Figure 16 Parameter set assignment of BP outputs (fixed allocation)



The configuration of the binary output function is basically the same as for the oth-er protection functions. Open the configuration dialog by double clicking with theleft mouse button on the symbol or via the context menu.

The signals of the binary output function are divided into two groups for “De-fault” and “General purpose” outputs.

Default

The default groups are signals which are exchanged between bayand station protection functions (e.g. distance protection trip forstarting the breaker failure protection). The station protection inputsignals (see Table 5) are all predefined and can’t be changed.Choice of the bay protection output signals (“General Purpose”, seeFigure 18), on the other hand, is unrestricted.

Figure 17 BP output (Default)

The signals assigned under the default group do not reduce thenumber of BP output channels (total of 120).

Location of ‘BP default’ output signals within the BP function di-agram see Figure 1, Label No. 14.



General Purpose

The “General Purpose” tab provides facility for defining up to 120 output signals.

Figure 18 BP output (General purpose)

Location of “BP general purpose” output signals within the BPfunction diagram see Figure 1, Label No. 12.

Edit (used for both “Default” and “General purpose” signals

Click on the respective “Edit” button to assign a “Default” or “General purpose”signal. This opens the dialog “Select binary input”. The remaining procedure is thesame as described for binary input signals (see Section 3.4.1.4).

Only bay protection output signals that are configured to a BPOutput Channel can be assigned to an output relay of the bay unitby selecting the menu “Configuration/ Binary module/ Outputs”.Section 2.3.2.4 provides a list of available bay protection outputsignals.

Location of Binary module’ output signals within the BP functiondiagram see Figure 1, Label No. 13.



3.4.3 Recording a binary signal as an event

Only bay protection binary signals can be configured to be recorded as events thatare also configured via menu “Configuration/ Binary module” (output signals donot necessarily have to be assigned to output relays).

3.4.4 Disturbance recording of a binary signal

Binary output signals generated by bay protection functions can be configured fordisturbance recording, providing they are configured in the “General purpose” dia-log for the binary output function (see Figure 18).

Binary input signals of the bay protection functions can be configured for disturb-ance recording, providing they are configured in the “General purpose” dialog forthe binary input function (see Figure 14) and also as a binary input via the HMI500menu “Configuration/Binary module/Inputs” menu.

3.5 Protection function settings

The appropriate dialog for setting a protection function is opened by double click-ing the left mouse button on the respective symbol or via the context menu.

Figure 19 Protection function settings

The settings in the dialog for each protection function are described in detail inSection 5.

1MRK 505 353-UEN Section 4System functions


Section 4 System functions

4.1 BP Function Monitoring

The BP function monitoring (measurement of primary system values) is made un-der the “Operator mode”. The bay units licensed to include bay protection are listedin the overview dialog. To view the measurements, select a bay unit and click onthe “Continue” button or more directly, simply double click on the desired bay unitusing the left mouse button. The “Select function” dialog with a list of bay protec-tion functions and measurements available in the particular bay unit appears. Selectthe desired function either by double clicking on it or selecting and clicking on the'Open function' button.

The protection function measurement is automatically refreshed. Close the dialogeither by clicking on 'OK' or 'Cancel'.

Figure 20 Bay protection measurements

The primary system values are needed, for example, for checkingthe measuring direction of the distance protection function whilecommissioning the protection.

Section 4 1MRK 505 353-UENSystem functions


4.2 BP Licenses

The menu “Configuration / BP Licences” provides an overview of licensed andconfigured protection function groups for each bay unit is shown.

Figure 21 licensed BP function groups

4.3 CT grounding

The location at which the CT neutrals are grounded (line or busbar side) is of con-sequence to directional protection functions (Distance protection DIST, Directionalovercurrent definite time protection DIROCDT and Directional overcurrent inversetime protection DIROCINV).

The following table lists the functions with provision for configuring the locationof the CT neutral ground:

Table 43 CT grounding settingProtection function Provision for configuring the CT ground?Distance protection yes

Directional overcurrent definite time protection no

Directional overcurrent inverse time protection no

The default setting for the last two functions is busbar side, but if a Distance pro-tection function has been configured, its setting (line or busbar side) applies for thedirectional overcurrent functions as well.

1MRK 505 353-UEN Section 5Bay protection functions


Section 5 Bay protection functions

5.1 Application / Technical details

For detailed information about application and technical details of the bay protec-tion functions refer to Users Guide REB500/ REB500sys 1MRB520292-Uen Sec-tion 12 as follows:

Bay protection Function SectionLogic 12.15

Delay / integrator 12.16

DIST Distance protection 12.2

OCDT Definite time over and undercurrent protection 12.3

OCINV Inverse time overcurrent protection 12.4

DIROCDT Directional overcurrent definite time protection 12.5

DIROCINV Directional overcurrent inverse time protection 12.6

I0INV Inverse time earthfault overcurrent protection 12.7

OCINST Peak value over and undercurrent protection 12.17

OVDT Definite time over and undervoltage protection 12.8

CHKI3PH Three phase current plausibility 12.11

CHKU3PH Three phase voltage plausibility 12.12

Section 5 1MRK 505 353-UENBay protection functions


5.2 Technical additions

5.2.1 Voltage transformers for bay protection

The HMI500 “Settings/Voltage transformers/Overview” tab opens a dialog withthe list of all voltage transformers in the single-line diagram with their labels, baylabels primary and secondary rated voltages.

In the “Details” view the description can be edited in the input field “Markings”.The ratio is determined by the primary and secondary ratings entered in the “Trans-former ratio” input field. The VT input is a single winding, which is suitable for allthe main VT secondary ratings, the effective voltage being set via HMI500 to ei-ther 100 V or 200 V. Other voltages are accommodated by appropriately setting thescaling factor.

This menu item appears only if voltage transformers have been fitted.

Figure 22 Settings/Voltage transformers

1MRK 505 353-UEN Section 5Bay protection functions


5.2.1.2 Star point setting for bay protection

If a REB500 bay unit includes bay protection functionality with 3-phase voltage measurement, the mode of VT connection“3Phase_Star” is mandatory.

Setting example for BP applications

• VT data:

UN primary = 220 kV / √3

UN secondary = 110 V / √3

Connection to REB500: 3 phases_star (mandatory connection)

• Settings made in HMI500

VT connection: 3 phases_star (mandatory setting)

Primary voltage: 220,000 V

Secondary voltage: 100 V

Scaling factor: 1.1

5.2.1.3 Scaling factor setting for bay protection

The scaling factor only applies to the voltage functions and not todistance protection.

Section 6 1MRK 505 353-UENBP-Additions to base documentation


Section 6 BP-Additions to base documentation

6.1 Technical Data

The following information about bay protection functionality applies in addition tothe Product Guide of REB500.

Table 44 LogicFunction/ Parameter Range/ Value Accuracy

· Logic for 4 binary inputs with the following 3 configurations:1. OR gate2. AND gate3. Bistable flip-flop with 2 set and 2 reset inputs (both OR

gates), resetting takes priority

· 4 independent parameter sets

- -

All configurations have an additional blocking input. Provision for inverting all inputs.

Table 45 Delay/ integratorFunction/ Parameter Range/ Value Accuracy

• Pick-up or reset time 0 to 300 s in steps of 0.01 s -

• Integration yes/no -

· For delaying pick-up or reset or for integrating 1 binary signal· Provision for inverting the input· 4 independent parameter sets

1MRK 505 353-UEN Section 6BP-Additions to base documentation


Table 46 Distance Protection 21 (PDIS)Function/ Parameter Range/ Value

• Impedance measurement -300 to 300 W/ph in steps of 0.01 W/ph

• Zero-sequence current compensation 0 to 8 in steps of 0.01,-180° to +90° in steps of 1°

• Mutual impedance for parallel circuit lines 0 to 8 in steps of 0.01,-90° to +90° in steps of 1°

• Time step setting range 0 to 10 s in steps of 0.01 s

• Underimpedance starters -999 to 999 W/ph in steps of 0.1 W/ph

• Overcurrent starters 0.5 to 10 IN in steps of 0.01 IN

• Min. operating current 0.1 to 2 IN in steps of 0.01 IN

• Back-up overcurrent 0 to 10 IN in steps of 0.01 IN

• Neutral current criterion 0.1 to 2 IN in steps of 0.01 IN

• Neutral voltage criterion 0 to 2 UN in steps of 0.01 UN

• Low-voltage criterion for detecting, for example, a weak infeed 0 to 2 UN in steps of 0.01 UN

VT supervision• NPS/neutral voltage criterion• NPS/neutral current criterion

0.01 to 0.5 UN in steps of 0.01 UN0.01 to 0.5 IN in steps of 0.01 IN

Operating times of the distance protection function (including tripping relay)• minimum• typical

(see also isochrones• Figure 23)

20 ms25 ms

Typical reset time 35 ms

VT-MCB auxiliary contact requirements• Operation time <15 ms

· Five measuring stages with polygonal impedance characteristic forward and backward· All values of settings referred to the secondaries, every zone can be set independently of the others· 4 independent parameter sets

Accuracies Value

Amplitude error ±5% for U/UN >0.1

Phase error ±2° for U/UN >0.1

Applicable for current time constants between 40 and 150 ms

For details about distance protection operating times see Figure 23



Figure 23 Distance protection operating times



Table 47 Definite time over and undercurrent protection 51 (PTOC/PTUC)Function/ Parameter Range/ Value

• Pick-up current 0.2 to 20 IN in steps of 0.01 IN

• Delay 0.02 to 60 s in steps of 0.01 s

Reset ratio:• overcurrent• undercurrent

>94% (for max. function)<106% (for min. function)

• Max. operating time without delay 60 ms

• Inrush restraint (optional):• pick-up setting 0.1 I2h/I1h

· Over- and undercurrent detection· Single or three-phase measurement with detection of the highest, respectively lowest phase current· 2nd harmonic restraint for high inrush currents· 4 independent parameter sets

Accuracies Value

Accuracy of the pick-up setting (at fN) ±5%

Table 48 Inverse time overcurrent protection 51 (PTOC)Function/ Parameter Range/ Value

Inverse time characteristic(acc. to B.S. 142, IEC 60255-3 with extended setting range):

• normal inverse• very inverse• extremely inverse• long time inverse

t = k1 / ((I/IB)C - 1)

• c = 0.02• c = 1• c = 2• c = 1

• or RXIDG characteristic t = 5.8 - 1.35 x·ln(I/IB)

• Number of phases 1 or 3

• Base current IB 0.04 to 2.5 IN in steps of 0.01 IN

Pick-up current Istart 1 to 4 IB in steps of 0.01 IB

Min. time setting tmin 0 to 10 s in steps of 0.1 s

k1 setting 0.01 to 200 s in steps of 0.01 s

· Single or three-phase measurement with detection of the highest phase current· 4 independent parameter sets



Table 49 Directional overcurrent definite time protection 67 (PTOC)Function/ Parameter Range/ Value

• Current 0.02 to 20 IN in steps of 0.01 IN

• Angle -180° to +180° in steps of 15°


• Wait time 0.02 to 20 s in steps of 0.01 s

• Memory duration 0.2 to 60 s in steps of 0.01 s

• Voltage input range 0.005 to 2 UN

• Voltage memory range <0.005 UN

• Response time without delay 65 ms

· Directional overcurrent protection with detection of power flow direction· Back-up protection· 4 independent parameter sets· Three-phase measurement· Suppression of DC and HF components· Definite time characteristic· Voltage memory for near faults· Selectable response when power direction no longer valid (trip or block)

Accuracies Classes/ Value

• Accuracy of pick-up value ±5%

• Accuracy of angle measurement (at 0.97…1.03 fN) ±5°

• Reset ratio 95%



Table 50 Directional overcurrent inverse time protection 67 (PTOC)Function/ Parameter Range/ Value


• Angle -180° to +180° in steps of 15°



t = k1 / ((I/IB)C - 1)

• c = 0.02• c = 1• c = 2• c = 1

• t-min 0 to 20 in steps of 0.01

• IB-value 0.04 to 2.5 IN in steps of 0.01 IN

• Wait time 0.02 to 20 s in steps of 0.01 s

• Memory duration 0.2 to 60 s in steps of 0.01 s

• Voltage input range 0.005 to 2 UN

• Voltage memory range <0.005 UN


· Directional overcurrent protection with detection of power flow direction· Back-up protection· 4 independent parameter sets· Three-phase measurement· Suppression of DC and HF components· Inverse time characteristic· Voltage memory for near faults· Selectable response when power direction no longer valid (trip or block)



Table 51 Inverse time earthfault overcurrent protection 51N (PTOC)Function/ Parameter Range/ Value



t = k1 / ((I/IB)C - 1)

• c = 0.02• c = 1• c = 2• c = 1

• or RXIDG characteristic t = 5.8 - 1.35 x·ln(I/IB)

• Number of phases 1 or 3

• Base current IB 0.04 to 2.5 IN in steps of 0.01 IN

• Pick-up current Istart 1 to 4 IB in steps of 0.01 IB

• Min. time setting tmin 0 to 10 s in steps of 0.1 s

• k1 setting 0.01 to 200 s in steps of 0.01 s


· Neutral current measurement (derived externally or internally)· 4 independent parameter sets

Table 52 Peak value over and undercurrent protection 50 (PTOC/PTUC)Function/ Parameter Range/ Value


• Delay 0 to 60 s in steps of 0.01s

• Max. trip time with no delay (at fN) for max. function• Max. trip time with no delay (at fN) for min. function

£30 ms£60 ms

· Maximum or minimum function (over- and undercurrent)· Single or three-phase measurements· Wide frequency range (0.04 to 1.2 fN)· Peak value evaluation

Accuracies Value

Accuracy of the pick-up value (at 0.2 to 1.1 fN) ±5%

• Reset ratio for max. function• Reset ratio for min. function

• >90%• <110%



Table 53 Definite time over and undervoltage protection 59/27 (PTUV/PTOV)Function/ Parameter Range/ Value

• Pick-up voltage 0.01 to 2.0 UN in steps of 0.01 UN


• Max. operating time without delay 60 ms

· Over- and undervoltage detection· Single or three-phase measurement with detection of the highest, respectively lowest phase voltage· 4 independent parameter sets

Accuracies Value

Accuracy of the pick-up setting (at fN) ±2% or ±0.005 UN

• Reset ratio (U ³ 0.1 UN)• overvoltage• undervoltage

•• >95%• <106

Table 54 Three phase current plausibility 46 (PTOC)Function/ Parameter Range/ Value

• Pick-up differential for sum of internal summation current 0.05 to 1.00 IN in steps of 0.05 IN

• Amplitude compensation for summation CT -2.00 to +2.00 in steps of 0.01


· Determination of the sum and phase sequence of the 3 phase currents· 4 independent parameter sets

Accuracies Value

Accuracy of the pick-up setting at rated frequency ±2% IN in the range 0.2 to 1.2 IN

• Reset ratio ³90% whole range

Table 55 Three phase voltage plausibility 47 (PTUV)Function/ Parameter Range/ Value

• Pick-up differential for sum of internal summation voltage 0.05 to 1.2 UN in steps of 0.05 UN

• Amplitude compensation for summation VT -2.00 to +2.00 in steps of 0.01


· Determination of the sum and phase sequence of the 3 phase voltages· 4 independent parameter sets

Accuracies Value

Accuracy of the pick-up setting at rated frequency ±2% UN in the range 0.2 to 1.2 UN

• Reset ratio >95% (at U > 0.1 UN or I > 0.1 IN)



6.2 Operation and maintenance

The following information about bay protection functionality applies in addition tothe Operation Manual of REB500.

6.2.1 Maintenance of bay protection functions

Before checking the bay protection functions, consider the possible effect of, forexample, secondary injection on other protection functions such as the busbar andbreaker failure protection functions.

Where there is doubt, block the station protection functions by ap-plying the input signal “31205_Block SP” to the central unit.

6.2.2 Protection blocking

This section lists the indications and signals which occur when the bay protectionis blocked.

Table 56 BP blocked, central unit and bay unitsHMI text LEDs EventBP blocked Green lit, yellow

flashes until buttonon the local HMIpressed

CU: “49405_BP blocked” activeBU: “29405_BP blocked” active

6.2.3 Protection tripping

This section lists the indications and signals which occur when the bay protectiontrips.

Table 57 BP tripped, central unitHMI text LEDs EventDate TimeDIST tripFeeder name

Green lit,red lit

CU: None

Date TimeOCTD tripFeeder name

Green lit,red lit

CU: None

Date TimeOCINV tripFeeder name

Green lit,red lit

CU None

Date TimeI0INV tripFeeder name

Green lit,red lit

CU: None

Date Time Green lit, CU: None



HMI text LEDs EventOVSTD tripFeeder name

red lit

Date TimeDIROCDT tripFeeder name

Green lit,red lit

CU: None

Date TimeDIROCINV tripFeeder name

Green lit,red lit

CU: None

Date TimeOCINST tripFeeder name

Green lit,red lit

CU: None

Table 58 BP tripped, bay unitHMI text LEDs EventDate TimeDIST tripFeeder name

Green lit,red lit

BU: 2111xx_DIST TRIP CB Ly

Date TimeOCDT tripFeeder name

Green lit,red lit

BU: 212105_OCDT TRIP

Date TimeOCINV tripFeeder name

Green lit,red lit

BU: 213105_OCINV TRIP

Date TimeI0INV tripFeeder name

Green lit,red lit

BU: 221105_I0INV TRIP

Date TimeOVSTD tripFeeder name

Green lit,red lit

BU: 216105_OVSTD TRIP

Date TimeDIROCDT tripFeeder name

Green lit,red lit

BU: 214105_DIROCDT TRIP

Date TimeDIROCINV tripFeeder name

Green lit,red lit

BU: 215305_DIROCINV TRIP

Date TimeOCINST tripFeeder name

Green lit,red lit

BU: 226105_ OCINST TRIP

Date TimeCHKI3PH tripFeeder name

Green lit,red lit

BU: 224605_CHKI3PH Picked up

Date TimeCHKU3PH tripFeeder name

Green lit,red lit

BU: 225605_CHKU3PH Picked up



6.3 Commissioning

The following information about bay protection functionality applies in addition tothe Commissioning Manual of REB500.

6.3.1 Regulations

DANGER: Note that when commissioning REB500 the analogueinput signals act on the bay protection functions as well as the sta-tion functions. Especially when the commissioning subsequently(e.g. following additions to the system), care must be taken to pre-vent part of the system which are already in operation from mal-operating. Corresponding precautions must be taken (interruptingtripping circuits, blocking system functions, disabling auxiliarytripping relays).

6.3.2 Additional checks for bay protection REB500

The following checks described below are necessary to commission the bay protec-tion function (in addition to the function test of REB500 station protection).

6.3.2.1 Commissioning a new station without any HV

When commissioning a new station or a station, which is not energized, the busbarand breaker failure protection functions and the bay protection functions (line pro-tection) can be commissioned separately, although certain tests do overlap andshould be coordinated to save time.

Note also that, for example, injecting current in the analog input of one feeder cantrip other feeders via the intertripping logic. This can, however, be prevented bytaking the appropriate precautions (interrupting tripping circuits, blocking stationprotection functions or blocking tripping relays).



6.3.2.2 Additions to an existing station

When adding bay protection to an existing station more checks have to be carriedout than is the case of a REB500 with only station protection. To avoid any risk ofthe station protection functions (BBP, BFP and EFP) being affected and possiblymal operating when performing the additional checks, the following procedure isrecommended. The basic philosophy is to check the bay unit on its own first (with-out the rest of the REB500 system). This is done in the stand-alone bay unit modeand requires that the setfile be loaded in the bay unit to be extended beforehand asfollows:

Step 1

Interrupt the optical fiber link between the central unit and the by unit to be com-missioned.

Step 2

Switch on the auxiliary supply to the new bay unit.

Step 3

Appropriately update the setfile of the REB500 in question to include the new bayunit (activate the feeder) and download it to the new bay unit. The setfile mustinclude all the settings needed for the new bay unit.

Step 4 (Check of the analogue inputs)

Refer to REB500 Commissioning Manual Sections “Checking the analog inputs(CTs)” and “Checking the analog inputs (VTs)”.

Measuring the start values of BP functions (e.g. distance protection function) is un-necessary, because they are fully processed by the software and any error would bedetected by the self-supervision function. However, it is normal to measure the re-actances of the various distance measuring zones. This may be omitted if a suitabletest set is not available.

Step 5 (Check the binary inputs and outputs)

Refer to REB500 Commissioning Manual Sections “Checking the binary input sig-nals”, “Checking the aux. contacts of isolators and circuit breakers” and “Checkingthe binary output signals”.

Step 6

Block the REB500 system (e.g. using “Block output relays” on the central unit).



Step 7

Download the updated setfile to the central unit.

This requires that the PC running HMI500 be connected either directly to the cen-tral unit or a bay unit, which is already operational.

WARNING: On no account connect the optical fiber link to thenew bay unit before the setfile has been successfully downloaded tothe central unit.

Step 8

• Switch off the bay unit• Connect the optical fiber cable going to the central unit• Switch on the bay unit

Step 9

Perform the busbar protection through-fault stability check (Refer to REB500Commissioning Manual Sections “Checking protection stability”)

Step 10

Check the direction of the distance protection function with load current. This isachieved by measuring real and apparent power in L1 phase.

The real and apparent power measurements of all the directional functions can beviewed by selecting the HMI500 menu “View/BP function monitoring”. The di-rection “Forwards” or “Backwards” is also displayed for both real and apparentpower as soon as a valid measurement has been made.

The display is influenced by the setting ‘CT Neutral’ “Line side/Busbar side” forthe distance protection function. The default setting of ‘CT Neutral’ for the dis-tance protection function is CTs grounded on the busbar side.

Note the following with respect to busbar protection:

The side on which the CTs are grounded is of no consequence for the busbar pro-tection and does not therefore have a setting. What is important, however, is thatthe grounding of all the CTs on the busbars is the same (and have the same windingsense), otherwise the differential current will not be correct.

Where this is not the case, the connections to the corresponding CT inputs on therespective bay units must be reversed (current phase-angle rotated by 180°).

In the feeders in which the current direction has been rotated in the bay unit by180°, the setting parameter 'CT Neutral' of the distance function must also be re-spectively corrected to correspond to actual earthing direction of the CT.



Step 11

Restore REB500 to normal operation.

6.4 Communication

The Communication Protocol Manuals describe the communication protocols sup-ported by the IED with a focus on vendor-specific implementations.

The communication signal engineering extends the basic signal engineering of BPdescribed in the present Application Manual. The cross reference list (see Table59) reflects the relationship between the Application Manual for BP and the rele-vant sections of the Communication Protocol Manuals.

Table 59 Cross referencesItem Topic see present Application Manual for BP Communication Protocol Manual / Section

1 Logical output signals Figure 1 à Item No. 5 IEC61850 / Bay protection specific signals

2 Configuring binary output signals Section 3.4.2 IEC61850 / Bay protection specific signals

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