Technical Note - TN 039: 2015

For queries regarding this document

standards@.transport.nsw.gov.au
www.asa.transport.nsw.gov.au

Technical Note - TN 039: 2015

Issued date: 30 June 2015

Effective date: 30 June 2015

Subject: RailCorp Electrical Network High Voltage

Feeders Pilot Wire Schematic Drawings

1. Introduction
The majority of high voltage feeders on the RailCorp electrical network have a pilot wire
protection scheme installed.

Where there is a pilot wire scheme installed, then in addition to the schematic diagrams produced
for the individual equipment at either end of the scheme, an overall "Pilot Wire Schematic"
drawing is required to be produced.

2. Modifications to existing pilot wire schemes

When an existing pilot wire scheme is being modified then the associated schematics and the
pilot wire schematic drawing must be modified.

If an existing pilot wire scheme is being modified and there is not an existing pilot wire schematic
drawing, then the project is responsible for producing a pilot wire schematic drawing.

Where an additional substation is installed between two existing substations and hence the
existing pilot wire scheme becomes two schemes there shall be a pilot wire schematic for each
individual scheme. The project is responsible for producing the pilot wire schematics.

3. Content and layout of pilot wire scheme drawing

The content of the pilot wire schematic diagram shall typically include the following for both ends
of the scheme:

High voltage busbars, associated ACCB's, ABSW's and links

State of NSW through Transport for NSW Page 1 of 3

 Technical Note - TN 039: 2015

Current transformers (including CT's used for other protection schemes) with secondary
circuitry connection to the pilot wire relay. CT's to be shown in correct position and
polarity identified.

Voltage transformers

Pilot wire relays and associated test blocks, with all connections to the PW relay detailed
and referenced to the equipment schematic drawings.

Auxiliary supply to the PW relay and SCADA alarms

Schematic representation of the communication scheme between PW relays

Relevant notes and an Item list

The following drawings provide examples of the typical content and layout to be included on the
diagram:

RailCorp drawing: EL0518527, Cardiff to Hamilton, 750 Feeder

RailCorp drawing: EL0498117, Edgecliff to Prince Alfred, 755 Feeder

RailCorp drawing EL0273924, Berowra to Cowan, 830 Feeder

4. Title block content

All drawings are required to comply with the RailCorp CAD manual. Specifically the content of the
title block for pilot wire scheme drawing is detailed in Table 1 below:

Table 1 Title block content

Line Description

LINE 1 Location X to Location Y (eg: PRINCE ALFRED TO ARGYLE)

LINE 2 Rail Corridor (eg: NORTH SHORE LINE)

LINE 3 SUBSTATIONS, XXkV FEEDER YYY (eg: SUBSTATIONS, 33 kV FEEDER 746)

LINE 4 PILOT WIRE PROTECTION

LINE 5 SCHEMATIC DIAGRAM

State of NSW through Transport for NSW Page 2 of 3

 Technical Note - TN 039: 2015

Authorisation:

Technical content Checked and Interdisciplinary Authorised for

prepared by approved by coordination release
checked by

Signature

Name Chris Lilly Neal Hook John Paff Graham Bradshaw

Position Principal Engineer Lead Electrical A/Chief Engineer Principal Manager

Substations and HV Engineer Network Standards &
Network Services

State of NSW through Transport for NSW Page 3 of 3

Engineering Standard
Electrical

Engineering Standard

EP 19 00 00 02 SP

PROTECTION SYSTEM

REQUIREMENTS FOR THE HIGH

VOLTAGE NETWORK

Version 4.1

Issued June 2012

Owner: Chief Engineer Electrical

Approved Neal Hook Authorised Neal Hook

by: Chief Engineer by: Chief Engineer
Electrical Electrical

Disclaimer
This document was prepared for use on the RailCorp Network only.
RailCorp makes no warranties, express or implied, that compliance with the contents of this document shall be
sufficient to ensure safe systems or work or operation. It is the document users sole responsibility to ensure that the
copy of the document it is viewing is the current version of the document as in use by RailCorp.
RailCorp accepts no liability whatsoever in relation to the use of this document by any party, and RailCorp excludes
any liability which arises in any manner by the use of this document.
Copyright
The information in this document is protected by Copyright and no part of this document may be reproduced, altered,
stored or transmitted by any person without the prior consent of RailCorp.

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Document control
Version Date Summary of change
June 2007 Last Technical Review
4.0 May 2010 Application of TMA 400 format
4.1 June 2012
Update list of Australian and RailCorp standards
Incorporate P543 & P124 standard test block
diagrams, input and output relay configuration
Incorporate a section on Rectifier transformer frame
leakage
Update Approved Protection Relay and incorporate
standard test block diagrams.
Update headings & numbering of section 6.2
Voltage transducer model changed to ISTAT 400
series.
Update Voltage transformer burdens
Incorporate a section for Voltage transformer for
11kV side of system transformers.
Update the metering requirements for 66, 33 &
11kV feeders
Added new appendix detailing metering
requirements for bulk supply locations.
Added new appendix detailing wire codes for CTs,
VTs and related equipment.
Incorporate 11kV overcurrent protection on system
transformers in ACCB Trip Coil table .
Incorporate a section for the Requirement for
capacity of batteries added.
Incorporate standard test block diagram for neutral
leakage protection.
Update Approved protection relays for new
switchboards.

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Contents

1 Introduction .............................................................................................................................6

2 Normative References ............................................................................................................6

2.1 International Standards..............................................................................................6

2.2 Australian Standards .................................................................................................6

2.3 RailCorp Documents..................................................................................................7

2.4 RailCorp Drawings.....................................................................................................7

2.5 Industry Publications..................................................................................................7

3 Definitions and Abbreviations ...............................................................................................7

4 General Protection Philosophy .............................................................................................8

4.1 General ......................................................................................................................8

4.2 Protection Settings.....................................................................................................9

4.3 Grading ......................................................................................................................9

5 Specific Protection Equipment Requirements.....................................................................9

5.1 Protection Equipment Design Principles - All New HV Switchgear...........................9

5.2 Interfacing New Protection Schemes With Existing Equipment ..............................10

5.2.1 Multiple Use of Current Transformers ......................................................10

5.2.2 Trip Circuit Supervision ............................................................................10

5.2.3 Breaker Fail ..............................................................................................10

5.2.4 Inter-trip ....................................................................................................10

5.3 Current Transformers (CT) ......................................................................................10

5.3.1 General Requirements .............................................................................10

5.3.2 Multiple Ratio Current Transformers ........................................................11

5.3.3 Protection Current Transformers..............................................................11

5.3.4 Measurement Current Transformers........................................................11

5.3.5 Current Transformer Secondary Wiring ...................................................12

5.4 Voltage Transformers ..............................................................................................12

5.4.1 General Requirements .............................................................................12

5.4.2 Voltage Transformer Secondary Wiring ...................................................13

5.4.3 Voltage Transformer Alarms ....................................................................13

5.4.4 Voltage Transformer Supply to Protection Relays ...................................13

5.4.5 Voltage Transformer for 11kV Side of System Transformers ..................13

5.5 Auxiliary Supply (DC)...............................................................................................13

5.5.1 General Requirements .............................................................................13

5.5.2 Requirement for Two battery Systems.....................................................14

5.6 Protection Relays.....................................................................................................14

5.7 Close Inhibit .............................................................................................................15

5.8 Protection Alarms ....................................................................................................15

5.9 Inter-Trip Arrangements...........................................................................................15

5.9.1 Preferred Technology...............................................................................15

5.9.2 Fibre Optic Pilots ......................................................................................15

5.9.3 Copper Pilots............................................................................................15

5.10 Integrated Support System......................................................................................16

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6 Specific Equipment Applications ........................................................................................16

6.1 33kV & 66kV Feeders..............................................................................................16

6.1.1 Standard Protection Schemes .................................................................16

6.1.2 Primary Protection....................................................................................16

6.1.3 Backup protection.....................................................................................16

6.1.4 Circuit Breaker Fail Scheme ....................................................................17

6.1.5 Location of Current Transformers ............................................................17

6.1.6 Metering Requirements ............................................................................17

6.2 11kV feeders............................................................................................................18

6.2.1 Standard Protection Schemes .................................................................18

6.2.2 Primary Protection....................................................................................18

6.2.3 Backup protection.....................................................................................18

6.2.4 Circuit Breaker Fail Scheme ....................................................................19

6.2.5 Location of Current Transformers ............................................................19

6.2.6 Metering Requirements ............................................................................19

6.3 High Voltage Busbars & Bus-Tie Cables.................................................................19

6.3.1 Primary Protection for Busbars ................................................................19

6.3.2 Primary Protection for Bus-tie Cables ......................................................20

6.3.3 Backup Protection ....................................................................................20

6.3.4 Location of Current Transformers ............................................................20

6.4 Rectifier Transformer and Power Cubicle................................................................20

6.4.1 Primary Protection....................................................................................20

6.4.2 Backup Protection ....................................................................................21

6.4.3 Rectifier Transformer Frame leakage ......................................................21

6.4.4 Circuit Breaker Fail Scheme ....................................................................21

6.4.5 Protection Interface Requirements...........................................................21

6.5 System Transformers ..............................................................................................21

6.5.1 Standard Protection Schemes .................................................................21

6.5.2 Primary Protection....................................................................................21

6.5.3 Backup Protection ....................................................................................22

6.5.4 Circuit Breaker Fail Scheme ....................................................................22

6.5.5 Neutral Leakage .......................................................................................22

6.5.6 Buchholz Relay ........................................................................................22

6.5.7 Location of Current Transformers ............................................................22

6.6 11kV/415V Transformers.........................................................................................23

6.6.1 Transformers Supplied from Ring Main Units ..........................................23

6.6.2 Transformers Supplied from SCADA Controlled ACCBs ........................23

6.6.2.1 Standard Protection Schemes ..................................................23

6.6.3 Primary Protection....................................................................................23

6.6.4 Backup Protection ....................................................................................23

6.6.5 Circuit Breaker Fail Scheme ....................................................................23

6.7 Documentation Requirements .................................................................................23

6.7.1 System Definition Review (SDR) Documentation ....................................24

6.7.2 Preliminary (PDR) & Critical Design Review (CDR)

Documentation .........................................................................................24

6.7.3 System Verification Review (SVR) Documentation .................................24

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Appendix A Protection Relays ..................................................................................................25

Appendix B ACCB Trip Coils - Standard Equipment Connection .........................................27

Appendix C Two Battery Systems (125V DC) - Standard Protection Equipment

Connection .............................................................................................................28

Appendix D Interfacing With Existing Pilot Wire Schemes....................................................29

Appendix E Current Transformers (33kV & 66kV)...................................................................30

Appendix F Current Transformers for 11kV Switchgear ........................................................32

Appendix G Protection Relay Identification.............................................................................33

Appendix H Standard Test Block Wiring & Input/Output Relay Configuration ....................34

Appendix I Voltage and Current Transducers........................................................................54

Appendix J Pilot Wire Schemes ...............................................................................................55

Appendix K Auto Re-close on High Voltage Feeders .............................................................56

Appendix L Protection SCADA Alarms ....................................................................................57

Appendix M Implementation Of SCADA Alarms & Control ....................................................59

Appendix N Typical ACCB Auxiliary Supply Arrangement ....................................................60

Appendix O Protection Relay Labelling Guidelines ................................................................62

Appendix P Standard Current Transformer Configurations ..................................................65

Appendix Q Metering Requirements For Bulk Supply Points................................................68

Appendix R Current Transformer, Voltage Transformer and General

Protection - Wire Identification Code ..................................................................70

Appendix S Protection Non-Compliances Particular to the ECRL Project...........................71

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1 Introduction
This document covers the Protection System requirements for the RailCorp High Voltage
AC Network for 11kV, 33kV, 66kV and 132kV system voltages.

This document does not include protection requirements for the 1500V DC system.

The Specific Protection Equipment Requirements (Section 5 and associated Appendix)

are common requirements for the entire high voltage network.

These protection requirements cover general design principles for protection schemes, as
well as requirements relating specifically to the protection equipment. They do not
include equipment used for detection and measurement of non-electrical protection
parameters (such as oil and gas sudden pressure change, fibre optic temperature
measurement), other than to specify necessary interface details.

The correct design, implementation and management of the overall protection system are
critical to the safe and reliable operation of the RailCorp power system. As such, all
design processes for the protection system must follow the RailCorp Engineering Design
Management Procedures.

All new installations, modified and refurbished existing installations must comply with the
requirements in this document.

High voltage protection systems existing at the date of release of this document are not
affected by the requirements of this document.

2 Normative References
The following documents are either referenced in this standard or can provide further
information. The edition is current at the time of publication of this document.

2.1 International Standards

IEEE C.37.2 - 2008 Standard electrical power system device function numbers and
contact designations.

2.2 Australian Standards

AS 1243: 1982 Voltage Transformers for Measurement and Protection
AS 1675: 1986 Current Transformers Measurement and Protection
AS 2067: 2008 Switchgear assemblies and ancillary equipment for alternating
voltages above 1 kV
AS 60044.1: 2007 Instrument Transformers part 1: Current Transformers
AS 60044.2: 2007 Instrument Transformers part 2: Single Phase Inductive
Voltage Transformers

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2.3 RailCorp Documents

EP 00 00 00 01 TI RAC Electrical system General Description
EP 06 00 00 01 SP System Substation Battery
EP 00 00 00 12 SP Electrical Power Equipment Integrated Support Requirements
EP 00 00 00 13 SP Electrical Power Equipment Design Ranges of Ambient
Conditions
EP 00 00 00 15 SP Common requirements for Electrical Power Equipment
EP 00 00 00 00 MP Electric Power Technical Maintenance Plan
EP 03 02 00 01 SP Controls and Protection for Rectification Equipment
EP 99 00 00 02 SP System Commissioning tests
EP 01 00 00 01 SP 33kV AC Indoor Switchgear Non-Withdrawable
EP 01 00 00 04 SP 33kV Outdoor Live Tank Circuit Breaker and Post Type CTs
EP 01 00 00 05 SP 33kV Outdoor Dead Tank Circuit Breaker Assembly
EP11 00 00 07 SP Design Technical Reviews for Electrical SCADA Equipment

2.4 RailCorp Drawings

EL 0283030 33KV Transformer Frame Leakage Arrangement

2.5 Industry Publications

Network Protection & Automation Guide (Alstom) (previously titled: Protective Relays
Application Guide)
Schneider/Alstom/Areva Protection Relay Application Guides

3 Definitions and Abbreviations

ACCB Alternating current circuit breaker

DC Auxiliary Supply Supply for the operation of electronic protection relays,

energisation of multi-trip relay coils, energisation of HV ACCB trip and close coils and
general control circuit operations. Nominally 125V DC or 48V DC.

CT(s) Current Transformer(s)

DC Direct Current

Dedicated Pilot Cable A communication cable that is used only for the control, indication
and pilot wire functions between two substations. The cable is continuous between
substations.

FAT Factory acceptance test

ILIS Acronym for Intelligent Light Information System which is a RailCorp

approved busbar fault detection scheme in use on Areva/Schneider WSA GIS
switchgear.

IT Inter-trip

Low Voltage Compartment The compartment on the high voltage switchgear where the
protection relays, control equipment and wiring is installed. The compartment is usually
accessed by a hinged door and does not require any isolation or operation of the
switchgear for safe access.

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MTA Protection relay used for the multi-tripping of ACCBs. This is a automatically reset
relay with a hand reset flag.

MTM Protection relay used for the multi-tripping of ACCBs. This is a manually reset relay
with a hand reset flag.

Pilot Wire RailCorps line differential protection schemes consist of schemes

implemented with numerical relays and schemes with translay relays. The majority of
documentation still refers to line differential schemes as pilot wire , even when
implemented with numerical relays.

Substation The following are locations within the RailCorp electrical network which are
classified as system substations for the purpose of this document.

Any location that includes a high voltage circuit breaker.

Traction substation
High voltage switching station
High voltage switchroom (except 2kV)

2kV locations, RMU locations that have an ACCB for the transformer, pole top and other
distribution substations that use HV fuses for protection are not classed as system
substations.

RMU Acronym for ring main unit.

RTU Remote Terminal Unit (Interface to SCADA system)

SCADA Supervisory Control and Data Acquisition system.

Supervisory A connection to the Electrical Operating Centre to allow the remote

operation of equipment and provision for remote monitoring of status and alarms using a
SCADA system.

4 General Protection Philosophy

4.1 General
In designing the protection schemes for RailCorps high voltage network, the following
general principles shall be applied:

All high voltage faults shall be detected and able to be cleared by two independent
sets of protection (primary and backup). Either may be circuit breakers or fuses.
The primary and backup protection schemes shall be independent. All HV circuit
breakers shall be equipped with dual trip coils.
Where primary and backup protection is installed in the same substation, that
substation shall have two battery systems. Some substations are exempt from this
requirement. This exemption is based on risk exposure considering safety, operational
impact, economic and environmental considerations.
The rated continuous thermal current of the CTs shall not constrain the rating of
associated power system elements.
Primary protection shall be implemented using unit schemes wherever practical.
The protection schemes shall be designed to eliminate or manage blind spots.

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4.2 P
rotection Settings
The protection shall be set to operate at not more than 2/3 of the minimum phase to
phase fault and not more than 2/3 of the minimum earth fault.
The overcurrent protection settings shall, as far as practicable, be at least 1.5 times
the maximum load current.
Fault clearing times shall be minimised.

4.3 G
rading
The protection shall be graded to ensure that the fault is cleared by the protection
closest to the fault, and the area of interruption is minimised.
A 0.3 second grading margin shall be provided as far as practicable for protection in
series except that breaker fail timers shall be 0.2 second.
Relay settings shall be, as far as practicable, at least 1.5 times the highest
downstream setting.

5 Specific Protection Equipment Requirements

5.1 Protection Equipment Design Principles - All New HV

Switchgear
To ensure the independence and integrity of protection schemes the following principles
shall apply:

Protection current transformers shall be connected to protection equipment only.

Approved transducers used for interfacing with the SCADA are to be regarded as
protection equipment. Appendix I lists approved transducers.
Primary and backup protection schemes shall be implemented using separate current
transformers (refer to Section 5.2.1 for exception) and relays.
Where the primary and backup scheme trip the same HV circuit breaker, the following
shall apply:

The primary and backup schemes shall use separate trip coils, one trip coil for
the primary scheme the second trip coil for the backup scheme. Refer to
Appendix B for standard trip coil arrangements and Appendix N for typical HV
switchboard arrangements.
The backup scheme (protection relay, trip coil control and supply) shall have its
auxiliary supply from a dedicated circuit originating at the distribution board.

Where two DC auxiliary supplies are required (see Section 5.5) the primary protection
scheme is to be supplied by battery A and the backup protection scheme supplied by
battery B.

SCADA monitored trip circuit supply supervision with local indication shall be
provided for all tripping circuits. The TCS scheme shall monitor with the ACCB
in the open or closed position.
The auxiliary supply for each bus-zone protection scheme (protection and multi-
trip relays) shall have its auxiliary supply from a dedicated circuit originating at
the distribution board. Fuse protection and monitoring shall be provided with the
monitoring relay connected to the SCADA system.
Individual protection schemes to be connected to dedicated current
transformers.

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5.2 Interfacing New Protection Schemes With Existing Equipment

5.2.1 Multiple Use of Current Transformers

It is acceptable to have more than one protection scheme (maximum two schemes)
connected to the same set of CTs as long as the following applies:

It is not economically feasible to install additional CTs (eg. Circuit breaker would have
to be replaced; additional post type CTs would be required.)
The protection schemes are not the primary and backup protection for the same
equipment.
A failure of the CTs will not result in a piece of equipment having no protection due to
an existing compromise in the protection system.
The output of the current transformers shall be sufficient for the burden of all the
connected protection schemes and associated equipment to ensure each scheme
operates as required up to the available fault level.

5.2.2 Trip Circuit Supervision

Where a new protection scheme is interfacing with existing switchgear that does not have
trip circuit supervision (TCS), TCS shall be implemented either as a function of the
protection relay (if available) or installation of a dedicated TCS relay (refer Appendix A).

5.2.3 Breaker Fail

When new protection relays that have breaker fail functionality are installed in an existing
substation, the breaker fail detection shall result in the energising of a multi trip relay. The
multi-trip relay shall trip all the associated ACCBs on the busbar.

5.2.4 Inter-trip
If the breaker fail function is associated with a feeder that does not have a dedicated
ACCB, then it is acceptable to implement an inter-trip by destabilising the pilot wire
schemes of feeders that are a possible source of fault current. When destabilising the
pilot wire schemes this must be implemented at the pilot wire relay.

5.3 Current Transformers (CT)

5.3.1 General Requirements

All protection and metering CTs shall comply with AS 60044.1, unless they are required
to interface with existing protection schemes that have CTs specified to AS 1675.

The CT shall be easily replaceable and shall be installed with polarity markings assuming
supply from the bus in all cases. All secondary leads shall be terminated in individual
links in the appropriate compartment where the CT is installed and the earth point formed
by using a proprietary cross connection for the links being used. The CTs shall be
earthed at one point. This single point earth is to be within the applicable LV
compartment.

CTs shall be rigidly clamped to prevent movement under short circuit conditions. They
shall be provided with rating plates and terminal markings as specified in AS 60044.1.
The rating plates shall be mounted in such a manner that they are visible, and the
secondary terminals shall be readily accessible. Duplicate rating plates shall be mounted
in the instrument compartment with connection diagram.

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The majority of existing CTs installed in the RailCorps system has a rated secondary
current of 5A. With the installation of GIS switchgear, the reduced space available for
CTs has resulted in the necessity to install CTs with a rated secondary current of 1A.

CTs shall safely withstand the mechanical and thermal stresses set up by a short circuit
equal to the full short circuit rating of the switchgear. CTs shall have a minimum rated
continuous thermal current of at least 150% of rated primary current unless modified by
the RFT for the specific location.

See Section 6.1.5 for CT location requirements for 33 & 66kV Feeders.

See Section 6.2.5 for CT location requirements for 11kV Feeders.

See Section 6.3.4 for CT location requirements for HV Busbars and Bus-Ties.

See Section 6.5.7 for CT location requirements for System Transformers.

5.3.2 Multiple Ratio Current Transformers

Where multiple ratio CTs are used, the links associated with changing the CT ratio shall
be fit for purpose.

The CT terminals shall be clearly marked to enable correct changing of the ratio. The
associated rating plate shall also be marked with the information to enable correct
changing of the ratio.

5.3.3 Protection Current Transformers

Protection CT shall be of a class entirely suitable for the connected equipment so as to
give correct operation under all service and fault conditions.

The following is the standard accuracy class:

Differential schemes 5P
Overcurrent & earth fault 10P

The rated short-time is 3 seconds.

The rated short time current shall have a minimum rating equal to the short time
withstand current of the associated switchboard or circuit breaker.

Appendix B has a table listing the typical ratio and designation of current transformers,
which are preferred for use in the RailCorp electrical network.

5.3.4 Measurement Current Transformers

Measurement CTs shall be of a class entirely suitable for the application as specified in
AS 60044.1.

As a general guide the following are typical class of accuracy used in the RailCorp
network:

0.5 class for general tariff metering such as supplies to shops, workshops etc.
2.0 class for general measurement such as transducers and ammeters.

The measurement current transformers shall have the same ratio and rated continuous
thermal current as the associated protection CTs on the circuit.

Refer to Appendix Q for specific current transformer requirements applicable to bulk

supply points.

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5.3.5 Current Transformer Secondary Wiring

All CT secondary wiring shall be provided with test links at the marshalling strip within the
respective low voltage compartment. The test links shall be Weidmuller SAKC10.

The wiring shall be connected to the associated protection relay (or meter) via a test
block that allows isolation of the relay / metering and short-circuiting of the current
transformer secondary. If the relay test blocks are not integral with the relay enclosure,
test blocks of the type Schneider MMLG01 shall be provided.

The test blocks shall be located adjacent to the respective protection relay.

The current transformer secondary wiring shall be coloured as detailed below:

A : red
B : white
C : blue
Neutral : black
2
The wiring shall be a minimum size of 2.5mm and have an insulation rating of 0.6/1 kV.
2
Where 2.5mm wiring is used it shall have a stranding of 50/0.25mm. All wiring
connections to CTs and to protection relays shall be made using double grip ring type
pre-insulated crimp lugs.

Wiring identification shall be in accordance with Appendix R.

Refer to EP 00 00 00 15 SP Common Requirements for Electrical Power Equipment, for

details of cable identification requirements.

5.4 Voltage Transformers

5.4.1 General Requirements

Voltage transformers shall be provided for all three phases and can either be a 3 phase
voltage transformer or 3 single phase voltage transformers.

Voltage transformers shall be manufactured and tested in accordance with AS 60044.2.

They shall have a rated primary voltage as specified by the switchgear and the number of
secondary windings will depend if a residual protection class winding or a metering class
winding is required in addition to the protection class winding.

The voltage factor shall be 1.9 for 30 seconds.

PERFORMANCE
RATED VOLTAGE ACCURACY CLASS RATED BURDEN
CATEGORY
Protection 110/3 V 3P 50VA
Metering 110/3 V 0.5 50VA

Table 1 - Voltage Transformer Specifications for Indoor Switchgear

The neutral point of the star connected primary shall be earthed. The neutral point of the
star connected secondary winding shall be brought out and connected to suitably
insulated terminals located in the LV compartment and earthed.

The voltage transformers shall be protected by suitably rated circuit breakers connected
in the low voltage circuit as close as possible to the transformer terminals.

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High voltage fuse protection of VTs is not mandatory and is only required where
necessitated by equipment design.

The requirement for a residual winding is dependent on the type of protection relays to be
used.

For maintenance, and for the commissioning of protection relays, it shall be possible to
simulate the voltage conditions that would occur during earth faults and the supplier shall
explain how this is achieved. A typical way to achieve this is to remove the high-voltage
fuse in any one phase and earth that phase of the voltage transformer.

5.4.2 Voltage Transformer Secondary Wiring

The voltage transformer secondary wiring shall be coloured as per the current
transformer wiring with the exception of any open delta wiring, which shall be purple.

Terminal blocks for VT secondary wiring shall provide 4mm sockets for the connection of
test equipment.

5.4.3 Voltage Transformer Alarms

A three phase, phase failure relay shall be connected to the star connected secondary
winding of the voltage transformer. The phase failure relay shall provide a normally
closed 'VOLTAGE TRANSFORMER FAIL' alarm contact as well as visual indication. The
relay shall detect both under-voltage and negative phase sequence voltage unbalance on
the load side of the main circuit breaker.

5.4.4 Voltage Transformer Supply to Protection Relays

The VT supply to protection relays shall be via a dedicated circuit breaker for each
protection relay. The circuit breaker shall have a voltage free auxiliary contact which is
connected to the SCADA system to give an FEEDER XXX DIRECTIONAL VOLTAGE
FAIL' alarm.

5.4.5 Voltage Transformer for 11kV Side of System Transformers

All system transformers shall have a voltage transformer connected to the 11kV side of
the transformer. The voltage transformer shall normally be located on the 11kV
switchboard on the line side of the 11kV ACCB. The voltage transformers shall be
provided for all three phases and shall be single phase voltage transformers.

5.5 Auxiliary Supply (DC)

5.5.1 General Requirements

The following are general requirements for the arrangement of auxiliary supplies to
protection circuits and ACCB control.

All ACCBs shall be individually supplied from the 125V DC or 48V DC distribution
board(s). The majority of RailCorp locations have an auxiliary supply of 125V DC, other
locations have a supply of 48V DC.

In each ACCB, distinct control circuits and equipment shall be individually fused. The
fuses shall be sized to ensure there is discrimination.

The following is a list of typical ACCB circuits and equipment that would be individually
protected by fuses.

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electronic protection relays

trip coil circuits
close control circuit
motor/spring charge circuits
alarm & indication circuits
DC/DC power supplies (eg. ILIS power supply, transducer supplies)
Buszone protection scheme

5.5.2 Requirement for Two battery Systems

To ensure integrity of the RailCorp electrical network is maintained when an auxiliary
supply fails, strategic substations are required to have two independent substation battery
systems.

The criteria determining this requirement are:

Connectivity of the substation (4 or more high voltage feeders) within the RailCorp
electrical network.
Maximum high voltage fault level and the margin to the rated short-time withstand
current capacity of the switchgear installed at the substation.
Criticality of the substation within the rail system. (eg. Main supply substation for city
circle, rail tunnel, rail junction, last traction substation on a radial rail line).
Where primary and backup protection is installed in the same substation, that
substation shall have two battery systems. Some substations are exempt from this
requirement. This exemption is based on risk exposure considering safety, operational
impact, economic and environmental considerations.
Complexity of the protection schemes and any resulting compromises in the protection
coordination.

The associated main distribution boards of the battery systems are to be capable of being
paralleled.

The two battery systems shall be of equal capacity and individually be rated for the full
load and duty cycle of the substation. Refer to EP 06 00 00 01 SP System Substation
Battery for further details.

Refer to Section 5.1 and Appendix C for specific requirements relating to protection
schemes when there are two auxiliary supplies at a substation.

5.6 Protection Relays

All protection relays shall be flush mount and withdrawable. The auxiliary supply to the
protection relays shall be 125V DC or 48V DC as determined by the existing substation
battery or specified in the protection concept design.

Appendix A has a table listing the protection relays which are currently approved for use
in the RailCorp electrical network.

When specifying the type of protection relay to be used consideration must be given to
ensure adequate integrated system support including availability of system spares.

Alternatives to relays specified in Appendix A must be approved by the Chief Engineer,

Electrical Systems.

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5.7 Close Inhibit

Where a protection operation results in an MTM relay being energised, the MTM relay
shall have normally closed contacts in the closing circuit of all the HV ACCBs that were
tripped by the MTM. This is to prevent the ACCBs from being closed. This is applicable
for all protection schemes.

System transformers and 11kV/415V transformers shall have a close inhibit contact in
both the primary and secondary ACCB closing circuits where fitted.

5.8 Protection Alarms

Every operation of a protection relay shall result in an individual alarm being sent to the
SCADA system and provide a local indication. The alarm shall enable the Electrical
System Operators to accurately identify the protection scheme that has operated.

If a protection relay has more than one function (eg A and C overcurrent elements),
then where practical each function shall have a separate alarm output.

Refer to Appendix L for a detailed listing of SCADA alarms.

5.9 Inter-Trip Arrangements

5.9.1 Preferred Technology

Optical fibre pilots are preferred for inter-tripping.

Refer to Appendix A for protection relays currently preferred for use in the RailCorp
Electrical Network for type of inter-trip relay.

5.9.2 Fibre Optic Pilots

Where fibre optic pilots are available, the inter-tripping may be achieved utilising pilot wire
relays that have inter-tripping as a function of the relay.

5.9.3 Copper Pilots

Where inter-trip arrangements are required for a feeder, it is preferred the inter-trip
scheme is implemented using a dedicated pair of pilots for the scheme.

If there are no spare pilots in the existing pilot cable, the inter-trip may be achieved by
manipulating the feeder pilot wire scheme.

A minimum of 15kV isolation shall be provided to avoid transfer of voltages across the
pilots. This may be achieved by using an inter-trip relay that provides isolation at both
ends of the scheme.

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5.10 Integrated Support System

An Integrated Support System exists for protection equipment. This current system is
based on 5 Amp CTs and protection relays nominated in Appendix A. An economically
justified integrated support analysis is required for any proposal to use non preferred
schemes, relays or CTs. The analysis shall include relevant requirements of
EP 00 00 00 12 SP and take account of the following:

Test and support equipment

Relay programming software
Staff training
Spares analysis and procurement
Maintenance requirements analysis
Operation and maintenance manuals

6 Specific Equipment Applications

6.1 33kV & 66kV Feeders

6.1.1 Standard Protection Schemes

The following schemes shall be provided for the protection of 33kV and 66kV feeders:

RailCorp network feeder Bulk Supply Feeder

Directional over-current and earth
fault (looking towards supply point)
and
Primary Protection Pilot wire
Pilot wire or
Distance protection (zone 1, last
20% Zone 2) at the supply end
over-current and earth fault
(may be directional if required by
In accordance with the other
Backup Protection system configuration to achieve
Network Operators policy
discrimination) and
circuit breaker fail

Table 2 - 33kV & 66kV Feeder Protection Schemes

6.1.2 Primary Protection

If the pilot circuit is not run via a dedicated pilot cable, an instantaneous over-current and
earth fault check relay shall be provided in series with the trip from the pilot wire relay to
prevent nuisance tripping of the feeder.

All pilot wire schemes shall include pilot circuit supervision. This may be implemented
either as a function of the pilot wire relay or using dedicated pilot circuit supervision
equipment.

6.1.3 Backup protection

The unit protection on the feeder shall be backed up by an over-current and earth fault
scheme. This scheme shall operate via a circuit breaker and current transformers that are
not part of the primary scheme.

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6.1.4 Circuit Breaker Fail Scheme

The failure of a circuit breaker to open in response to a protection trip command shall be
detected and the appropriate upstream circuit breaker(s) tripped. A time delay shall be
provided to avoid nuisance tripping.

It is preferred that the feeder pilot wire relay provides this function. Where the pilot wire
relay does not have this function an overcurrent and earth fault relay (with directional
capabilities) shall be provided to implement the breaker fail scheme. A contact from the
pilot wire relay shall be connected to the overcurrent and earth fault relay, which will
initiate an internal timer (nominally set to 0.2s). If the fault has not been cleared within this
time all possible sources of supply shall have their ACCBs tripped. All ACCBs on the
same busbar section as the failed ACCB shall be tripped via a multi-trip relay.

The buszone multi-trip relay shall be used for this purpose where fitted, otherwise the
multi-trip relay shall be an MTM relay for an indoor switchboard and an MTA relay for an
outdoor busbar.

6.1.5 Location of Current Transformers

It is preferred that the CTs are located on the busbar side of the feeder circuit breakers.

However where this is not practicable, the current transformers for feeder protection may
be located on the line side of the feeder circuit breaker. In this arrangement an inter-trip
shall be provided to trip the feeder circuit breaker at the far end of the feeder whenever
the local feeder circuit breaker is tripped. The far end circuit breaker is only required to
trip if fault current is flowing through that circuit breaker.

Refer to Section 5.9 Inter-Trip Arrangements for further details on inter-tripping.

See Appendix J for typical Pilot Wire arrangements.

6.1.6 Metering Requirements

Every feeder shall be provided with an ammeter and all bulk supply feeders shall be
provided with kWh metering.

The metering on a bulk supply feeder shall be duplicated as follows:

One set of metering for revenue checking by RailCorp.

Second set of metering that shall comply with the current National Electricity Rules,
the Service and Installation Rules of NSW and local Supply Authority. The meter shall
be connected to a dedicated current transformer.

Refer to Appendix Q for specific current and voltage transformer requirements applicable
to bulk supply points.

Details of the ammeter, metering and their connection are specified in the appropriate
switchgear standard.

The requirements for 33kV indoor switchgear are detailed in EP 01 00 00 01 SP 33kV AC

Indoor Switchgear Non-Withdrawable.

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6.2 11kV feeders

6.2.1 Standard Protection Schemes

The 11kV network supplies a large variety of installations with varying degrees of
operational criticality. These installations range from underground stations, major signal
boxes to minor maintenance locations supplied from pole mounted transformers.

The criticality of the installation, accessibility of the 11kV feeder and the fault level
determines the type of protection to be provided.

6.2.2 Primary Protection

The following list details the requirement for the primary protection to be a pilot wire
scheme.

11kV feeders supplying underground railway stations.

11kV feeders supplying major signal boxes
11kV feeders installed in tunnels
11kV feeders supplying installations deemed to be operationally critical
11kV feeders where it is time critical to clear the fault due to high fault levels or
bushfire hazards.

All pilot wire schemes shall include pilot circuit supervision. This can be implemented
either as a function of the pilot wire relay or using dedicated pilot circuit supervision
equipment.

Where the primary protection scheme is not required to be a pilot wire scheme, the
feeder shall be protected with an over-current and earth fault scheme.

6.2.3 Backup protection

The primary protection on the feeder shall be backed up by an over-current and earth
fault scheme.

Where the primary protection is a pilot wire scheme, the backup over-current and earth
fault scheme can be located on the same circuit breaker panel, however the scheme
must operate via a separate protection relay and ACCB trip coil.

Where the primary protection is not a pilot wire scheme, the backup over-current and
earth fault scheme shall operate via a circuit breaker and current transformers that are
not part of the primary scheme.

Where the primary protection is an overcurrent and earth fault scheme and is located on
a 11kV switchboard supplied directly from a transformer, a neutral leakage relay shall be
used as backup protection for earth faults.

The transformer primary overcurrent protection may be used to backup feeder

overcurrent protection. This is subject to the transformer overcurrent settings being
suitable.

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6.2.4 Circuit Breaker Fail Scheme

The failure of a circuit breaker to open in response to a protection trip command shall be
detected and all ACCBs on the same busbar section as the failed ACCB shall be tripped
via a multi-trip relay. The multi-trip relay used to implement this may be the bus-zone
multi-trip relay where fitted, otherwise the multi-trip relay shall be an MTM relay for a
switchboard.

If the feeders are protected by a pilot wire scheme then the appropriate upstream circuit
breaker(s) shall be tripped. A time delay (0.2s) shall be provided to avoid nuisance
tripping.

It is preferred that the protection relays provide this function.

6.2.5 Location of Current Transformers

It is preferred that the CTs are located on the busbar side of the feeder circuit breakers.

However where this is not practicable, the current transformers for feeder protection can
be located on the line side of the feeder circuit breaker. This is subject to RailCorp
approval.

6.2.6 Metering Requirements

Every feeder shall be provided with an ammeter and all feeders that are a dedicated
supply to commercial premises (eg, train maintenance centres) shall be provided with
kWh metering in accordance with the current National Electricity Rules and the Service
and Installation Rules of NSW where applicable.

Details of the ammeter, metering and their connection are specified in the appropriate
switchgear standard.

6.3 High Voltage Busbars & Bus-Tie Cables

6.3.1 Primary Protection for Busbars

All 33kV and 66kV indoor switchgear shall have bus zone protection as the primary
protection for the busbar.

The requirement for 11kV indoor switchgear to have bus zone protection depends
whether the location is a:

strategic location
location with high fault levels
location where there is more than one busbar section

The traditional high impedance bus-zone protection scheme using CTs is an approved
RailCorp scheme. A fault detection scheme that has been type tested and is an integral
system within the switchgear may be offered for consideration by RailCorp and if
approved will be the preferred scheme.

Strategically important outdoor 33kV and 66kV busbars shall also have high impedance
bus zone protection as the primary protection. The criteria for this decision will be
provided in a later version of this document.

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Separate schemes shall be provided for each section of the busbar. All ACCBs on the
associated bus-section shall be tripped. Close inhibit shall also be implemented, refer to
Section 5.7

The tripping of circuit breakers on an indoor switchboard shall be via a MTM relay. The
tripping of circuit breakers on an outdoor busbar shall be via an MTA relay.

6.3.2 Primary Protection for Bus-tie Cables

All bus-tie cables interconnecting 11kV, 33kV and 66kV indoor switchboards shall have
high impedance bus zone protection as the primary protection.

The scheme shall be arranged to trip the circuit breakers at both ends of the tie cable via
a manually reset multi-trip relay. Close inhibit shall also be implemented, refer to Section
5.7.

6.3.3 Backup Protection

The backup protection for a busbar shall be upstream over-current and earth fault
protection.

The backup protection for a bus-tie shall be upstream over-current and earth fault
protection except where the switchboard directly interfaces with a Supply Authority.
Where the switchboard interfaces with a Supply Authority the bus-tie cables shall have a
duplicate high impedance protection scheme as the backup protection. Refer to Appendix
A for the type of relay to be used.

6.3.4 Location of Current Transformers

The current transformers for protection of the busbar shall be located on the line side of
all circuit breakers.

The current transformers for protection of the bus-tie cables shall be located on the
busbar side of the tie circuit breaker.

Where the current transformers for the feeder, bus-tie, or transformer circuits are not
located on the busbar side of the circuit breaker and the bus zone scheme is used to
cover the blind spots between the circuit breakers and the CTs, then the bus-zone
scheme shall also initiate tripping of the circuit breakers at the far end of the feeder or tie
cable, or on the other winding of the transformer.

6.4 Rectifier Transformer and Power Cubicle

6.4.1 Primary Protection

The primary protection for the rectifier transformer and power cubicle shall be provided by
an A and C instantaneous overcurrent and instantaneous earth fault relay.

If the transformer is cable connected (terminals/bushings are not exposed), the circuit
breaker shall be tripped via a MTM relay for earth faults.

The overcurrent elements are required to operate when a fault on the +1500V DC busbar
(constant voltage arc of 400V between positive busbar and negative used in calculation)
is detected.

A current transducer shall be provided in the B protection circuit. The transducer output
shall be connected to the panel ammeter and analogue input to SCADA.

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See EP 03 02 00 01 SP Controls and Protection for Rectification Equipment, for further

detailed information on these requirements.

6.4.2 Backup Protection

The backup protection scheme for the rectifier transformer and power cubicle shall be
provided by a separate protection scheme, which is located in the same substation. The
protection relay shall be an A, B and C instantaneous overcurrent and
instantaneous earth fault relay.

If the transformer is cable connected, the circuit breaker shall be tripped via a MTM relay
for earth faults.

6.4.3 Rectifier Transformer Frame leakage

Rectifier transformers that have a roof structure covering the transformer shall have
frame leakage protection installed in addition to the primary and backup protection. This
protection shall monitor the current from the transformer tank to the substation earth
system.

A dedicated instantaneous relay (and test block) shall be installed in the same location as
the primary and backup protection relays for the rectifier transformer.

Refer to RailCorp drawing EL0283030 for further details.

6.4.4 Circuit Breaker Fail Scheme

The failure of the circuit breaker to open in response to a protection trip command shall
be detected and the associated bus-zone MTM relay shall be energised. A time delay of
0.2 seconds shall be provided to avoid nuisance tripping.

It is preferred that the protection relays provide this function

6.4.5 Protection Interface Requirements

Refer to EP 03 02 00 01 SP Controls and Protection for Rectification Equipment, for
further detailed information on the protection interface requirements.

6.5 System Transformers

6.5.1 Standard Protection Schemes

All 33kV and 66kV transformers 1MVA or greater in size shall have transformer
differential as the primary protection and overcurrent and earth leakage as the backup
protection. Oil filled transformers shall be fitted with a buchholz oil & gas relay.

6.5.2 Primary Protection

The transformer differential scheme shall be arranged to trip both the primary and
secondary circuit breakers.

The tripping of the circuit breakers shall be via a multi-trip relay. If the transformer is cable
connected (terminals/bushings not exposed) the multi-trip relay shall be a manually reset
relay.

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6.5.3 Backup Protection

Overcurrent and earth fault shall be provided as the backup transformer protection.

The tripping of the circuit breakers shall be via a multi-trip relay. If the transformer is cable
connected (terminals/bushings not exposed) the multi-trip relay shall be a manually reset
relay for earth faults and an automatically reset relay for overcurrent faults.

Three phase over current protection shall be provided on the low voltage side of the
transformer as backup protection to the outgoing feeder overcurrent protection.

6.5.4 Circuit Breaker Fail Scheme

The failure of a circuit breaker to open in response to a backup protection trip command
shall be detected and the associated bus-zone MTM relay energised. A time delay of 0.2
seconds shall be provided to avoid nuisance tripping.

The three phase overcurrent protection relay on the same side of the transformer as the
scheme being backed up shall provide this function.

6.5.5 Neutral Leakage

Neutral leakage shall be provided as backup protection to feeder earth fault. The scheme
shall trip both the primary and secondary circuit breaker of the transformer via an MTA
relay.

The neutral leakage relay shall be located on the 11kV switchboard.

6.5.6 Buchholz Relay

A buchholz relay shall be provided in the oil line between the conservator and the main
tank.

Operation of either the oil or gas element of the buchholz relay shall trip both the primary
and secondary circuit breakers via a manually reset multi-trip relay.

Each element of the buchholz relay shall have voltage free alarm contacts, which are
connected to the SCADA system.

6.5.7 Location of Current Transformers

It is preferred that the current transformers for the differential protection are located on
the busbar side of both the primary and secondary circuit breakers.

Where this is not practicable, it is acceptable that the current transformers for transformer
protection be located on the transformer side of the transformer circuit breaker.

The current transformer for the neutral leakage protection shall be located on the neutral
to earth connection of the transformer.

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6.6 11kV/415V Transformers

6.6.1 Transformers Supplied from Ring Main Units

All 11kV distribution transformers (200kVA and above up to 800kVA), that are supplied
via an ACCB from a RMU shall be protected by a protection relay. An Schneider
MMLG01 test block shall be fitted adjacent to the relay.

Transformers less then 200kVA shall be protected by fuses.

6.6.2 Transformers Supplied from SCADA Controlled ACCBs

6.6.2.1 Standard Protection Schemes

All 11kV transformers 1MVA or greater in size shall have transformer differential as the
primary protection and overcurrent and earth leakage as the backup protection. Oil filled
transformers shall be fitted with a buchholz oil & gas relay.

For transformers < 1MVA primary protection shall be overcurrent and earth leakage.
Transformer differential schemes may be used on smaller transformers where required to
ensure that the transformer protection grades over the LV protection.

6.6.3 Primary Protection

The transformer differential scheme shall be arranged to trip both the primary and
secondary circuit breakers.

The tripping of the circuit breakers shall be via a multi-trip relay. If the transformer is cable
connected (terminals/bushings not exposed) the multi-trip relay shall be a MTM relay.

6.6.4 Backup Protection

Overcurrent and earth fault shall be provided as the backup transformer protection.

The backup protection scheme is not required to detect faults on the LV winding of a
distribution transformer or the LV cables.

The tripping of the circuit breakers shall be via a multi-trip relay. If the transformer is cable
connected (terminals/bushings not exposed) the multi-trip relay shall be a MTM relay for
earth faults and an MTA relay for overcurrent faults.

6.6.5 Circuit Breaker Fail Scheme

The failure of a circuit breaker to open in response to a backup protection trip command
shall be detected and the associated bus-zone MTM relay energised. A time delay of 0.2
seconds shall be provided to avoid nuisance tripping.

It is preferred that the protection relays provide this function.

6.7 Documentation Requirements

There are several distinct stages for the submission of documentation related to the
protection design and implementation for RailCorp to review. These stages are aligned
with RailCorp Engineering Procedure EPD 0013 and required documentation is listed
below.

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6.7.1 System Definition Review (SDR) Documentation

The following documentation is required to be produced by RailCorp prior to the
procurement of any equipment that is required to comply with this standard:

Approved operating diagrams

Fault levels
Protection concept design. This document shall include:

Diagrams detailing the functionality of the protection schemes

Text document outlining in detail the protection schemes. This document shall
include such details as: functional description of protection schemes, current
transformer details, protection relay types, trip coil, SCADA alarms, analogue
details, auxiliary battery details.

Calculations (eg. CT knee-point voltage, VT burdens, fault levels)

High voltage equipment specifications

6.7.2 Preliminary (PDR) & Critical Design Review (CDR) Documentation

The following documentation is required to be submitted to RailCorp prior to the approval
of equipment manufacture.

Schematic diagrams
Equipment arrangement / layout drawings
Equipment label schedule

6.7.3 System Verification Review (SVR) Documentation

The following commissioning documentation is required to be submitted to RailCorp prior
to the energisation of equipment.

Equipment FAT test results

Primary injection test results
Secondary injection test results
Protection relay/scheme functionality checklists
Protection relay software setting files
Protection grading studies
Protection instructions
Equipment operating and maintenance manuals
As-built documentation (drawings, schedules etc)
Related test documentation to ensure the safe operation of the equipment (eg.
earthing test results)

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Appendix A Protection Relays

Approved Protection Relays

The following table details the approved protection relays for use in the RailCorp
electrical network when:

A new switchboard is to be installed

a new protection scheme is installed on existing equipment
an existing protection scheme is to be upgraded

SCHEME EQUIPMENT RELAY TYPE

MiCOM
Supply point feeder P521/P540/P541/P543,
Pilot Wire SIEMENS 7SD610
RailCorp feeder MiCOM P521/P541
Feeder MiCOM P127
Rectifier - primary MCAG33 or MiCOM P124
Rectifier - backup MiCOM P127
OC, EF, DOC, DEF Current check MiCOM P122
System Transformer MiCOM P127
11kV Distribution Transformer
VIP300LL
(refer Section 6.6)
Busbar MCAG34
Bus-zone MCAG34, P127 (when
Bus-tie cable
duplicate protection required)
Transformer differential SystemTransformer (2 winding) MiCOM P632
Transformer frame leakage Rectifier transformer MCAG14
Neutral leakage Transformer MiCOM P127
MTA MVAJ11 (with flag)
MTM MVAJ13 (hand reset with flag)
Used in conjunction with P521
Fibre to Cu converter MiCOM P595
relays on RailCorp feeders.
Intertrip GCM05 (15kV isolation)
TCS RMS 1TM10
48V DC supply RMS 1X10CAA
Bus Supply Monitoring
125V DC supply RMS 1X10EAA

Table 3 - Protection Relays

Notes:

The VIP300LL relay can not be used for transformers less then 200kVA as there may be
insufficient magnetising current to meet the self powering requirements of the relay.

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Location of Protection Relays & Test Block

The physical location of protection relays will depend on the type of switchgear installed.

The location is usually on the low voltage compartment of the switchgear panels (indoor
switchgear) or on dedicated protection panels (for outdoor ACCBs, indoor 66kV GIS or
indoor switchgear that does not have the physical space for installing the relays).

The test block shall be located adjacent to the protection relay to which it is connected
(right side of protection relay).

The particular location requirements for specific relays and equipment are detailed below:

Transformer protection rectifier transformer frame leakage, MTA and MTM relays
located on the primary protection panel.
33/11kV transformer neutral leakage relay shall be located on the 11kV switchgear
panel.
Bus-zone protection relay and associated MTM relay located on the appropriate end
panel.
Bus cable tie protection relay and associated MTM relay located on either of the
associated bus tie ACCB panels.
Pilot wire isolation transformers shall be located as close as possible to the
termination enclosure of the pilot cable.

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Appendix B ACCB Trip Coils - Standard Equipment Connection

The following table details the ACCB trip coils and associated relays that are connected
to each trip coil. This table is based on typical protection schemes used in RailCorp.
Protection designs for specific locations must be verified by RailCorp. Refer to 6.1.1 for
additional requirements relating to breaker fail schemes and Supply Points.

TRIP COIL
EQUIPMENT PROTECTION SCHEME NOTES
NUMBER
Pilot wire 1
Feeder Protection Overcurrent & Earth Fault 2
Inter-trip 1
Busbar protection trips via MTM 2 a
Bus-zone & Bus-Tie Cable Bus-tie protection trips via
1 d
MTM
Differential trips via MTM or MTA 1 f
33kVOvercurrent trips via MTA 1,2 b
System Transformers
Neutral Leakage trips via MTA 2
11kV Overcurrent 2
11kV/415V Differential trips via MTM or MTA 1
Transformers Overcurrent trips via MTA 1,2 b,e

Rectifier Transformers Instantaneous Overcurrent 1 c

(primary protn) Earth Fault 1 via MTM

Instantaneous Overcurrent 2
Rectifier Transformers c
(backup protn)
Earth Fault 2 & 1 via MTM

Rectifier Transformer MTM & frame leakage 1

Table 4 - Trip Coils

Notes:

a) The operation of the bus-zone protection energises an MTM relay, which trips
all ACCBs on the section of the busbar. The trip coil number applies to all
ACCBs that are tripped.

b) If the differential protection operates via an MTM then the overcurrent protection
shall trip via trip coil 2.

c) Refer to 6.4 for requirements of when earth faults are required to energise
MTM.

d) When there is duplicate protection on the bus-tie cable the duplicate scheme
shall trip the ACCBs via trip coil 2 (via an MTM).

e) If there is no differential protection, then the overcurrent protection shall trip via
trip coil 1.

f) Trip coil number applies to both ACCBs (eg. 33kV & 11kV)

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Appendix C Two Battery Systems (125V DC) - Standard

Protection Equipment Connection
The following table details the battery system that the ACCB trip coils and protection
relays should be connected to. This table is based on typical protection schemes used by
RailCorp.

When there are two battery systems the equipment should be connected across the two
battery systems to obtain balanced loads as close as possible.

Protection designs for specific locations must be verified by RailCorp. Refer to 5.5.2 for
details of the requirement for two battery systems.

PRIMARY & BACKUP

PRIMARY PROTECTION
PROTECTION LOCATED IN
ONLY
SAME SUBSTATION
ONE TRIP Protection relay supply from Primary protection relay supply
COIL one battery from battery 1
Trip coil supply from same Backup protection relay supply
battery as relay supply from battery 2
TWO BATTERY Trip coil supply from battery 1
SYSTEMS
TWO TRIP Protection relay supply from Primary protection relay supply
COILS battery 1 from same battery as the
associated supply to trip coil.
Trip coil 1 supply from battery
1 Backup protection relay supply
from same battery as the
Trip coil 2 supply from battery
associated trip coil and
2
different battery to primary
protection.
Table 5 - Two Battery Systems Connection of Equipment

Notes:

a) When there is only one battery system, the two trip coils must be supplied from
separate submains originating from the 125V DC distribution board.

b) Refer to Appendix N for typical arrangement of auxiliary supplies to HV

switchboards. This diagram illustrates the principle; however detailed design is
required to ensure security of the protection scheme.

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Appendix D Interfacing With Existing Pilot Wire Schemes

The following table details whether the existing pilot wire scheme needs to be upgraded
when a new switchboard is to be installed, and is interfacing with an existing pilot wire
protection scheme.

EXISTING SCHEME TO BE
SCHEME NOTES
EQUIPMENT REPLACED
Pilot wire HO2 YES
HO4 NO b
HMB4 YES
MHOB04 NO a
MBCI02 NO a
MiCOM P521/P541 NO
Table 6 - Interfacing With Existing Pilot Wire Schemes

Notes:

a) If there are fibre optic pilots available between substations or fibre is to be

installed, then pilot wire relays that use fibre optic for their communication
(MiCOM P521/P541) shall be used.

b) If system spares are to be used to create/interface with an H04 scheme then

the RailCorp Protection Engineer shall be consulted to ensure there are
adequate spares available. If the number of spares available is at the minimum
required number, then the pilot wire scheme shall be replaced.

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Appendix E Current Transformers (33kV & 66kV)

All current transformers to be installed in the RailCorp high voltage network are required
to be specified by a RailCorp designer with Engineering Authority for High Voltage
Protection.

The following tables detail the ratio and designation of the majority of current
transformers, which are used in the existing RailCorp electrical network for typical
schemes on the 66kV & 33kV high voltage system.

These tables do not detail current transformers used with 1A secondaries or for new
equipment or installations.

The current transformer designation details are calculated based on the following
parameters:

Maximum CT secondary lead (loop) length of 20m with 2.5mm2 size cable for indoor
equipment and a lead (loop) length of 150m with 16mm2 size cable for outdoor
equipment.
CT core knee point flux density of 1.45T
System X/R = 5
MICOM P521 relay, refer to general equations for X/R<40 and tIdiff = 0.1s.
MBCI relay, refer to general equations, X=1, large X/R, Kt = 20.
Overcurrent and earth fault relays, Vk = In*If*(Rrelay+Rct+Rleads), with relay burdens
as specified by the manufacturer.

Where the equipment to be protected is not in the following tables or the standard
parameters above are not applicable then the protection CT requirements must be
determined on an individual basis.

Typical examples of these scenarios are:

Lead lengths > 20m.

System transformers with a size or voltage not specified below.
Transformers with a different configuration.
Feeders with a higher capacity than 500A.

Rectifier Instantaneous Overcurrent & Earth Fault

RELAY
EQUIPMENT VOLTAGE/SIZE CT RATIO CT DESIGNATION
TYPE
10 P100F20 (specified on
MCAG33
5.3, 4.28 & 300/200/5 200 tap)
Rectifier Tx 33kV
2.5MVA 10 P50F20 (specified on
MiCOM P127
200 tap)
10 P100F20 (specified on
MCAG33
5.3, 4.28, 150/100/5 100 tap)
Rectifier Tx 66kV
2.5MVA 10 P50F20 (specified on
MiCOM P127
100 tap)

Table 7 - Rectifier Protection Relays & CTs

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Overcurrent and Earth Fault

CTs for use on overcurrent and earth leakage on feeders have been sized on a fault
level of 31.5kA at 33kV and 15.75kA at 66kV.

VOLTAGE CT
EQUIPMENT SCHEME RELAY TYPE CT DESIGNATION
/ SIZE RATIO
KCEG142 10P150
66kV Feeder OC & EF 250/5
MiCOM P127 10P150
10P300 (specified
KCEG142
500/400 on 300 tap)
33kV Feeder OC & EF
/300/5 10P300 (specified
MiCOM P127
on 300 tap)
33/11KV Tx (5MVA ) 33KV OC & EF 150/5 MiCOM P127 10P50F20

Table 8 - Overcurrent and Earth Fault Protection Relays & CTs

Pilot Wire Schemes

CTs for use on pilot wire schemes have been sized on a fault level of 31.5kA at 33kV
and 15.75kA at 66kV

EQUIPMENT CT RATIO RELAY TYPE CT DESIGNATION

MBCI02 or MiCOM
250/5 0.3PL115R0.3
P521/P541
66kV Feeder
MBCI02 or MiCOM
250/1 0.05PL50R0.8
P521/P541
MBCI02 or MiCOM 0.3 PL200R0.3 (specified
500/400/300/5
P521/P541 on 300 tap)
33kV Feeder
MBCI02 or MiCOM 0.05 PL80R0.8 (specified
500/400/300/1
P521/P541 on 300 tap)

Table 9 - Pilot Wire Protection Relays & CTs

Bus-Zone Schemes & Transformer Differential

The overall design of a bus-zone scheme is critical to ensure stability for through faults.
The requirement for stabilising resistors to ensure stability and for metrosils to limit CT
output voltage shall be determined for each individual scheme.

Please refer to the AREVA MCAG34 application brochure for methods of calculation and
requirements.

CTs for use on bus-zone schemes have been sized on a fault level of 31.5kA.

EQUIPMENT RELAY TYPE CT RATIO CT DESIGNATION

33kV Buszone MCAG34 1250/5 0.1 PL200R0.4
33/11kV Tx 5MVA, Dyn1 MBCH12 (two winding),
33kV - 150/5 2.5P50F20
(differential) MiCOM P632
Table 10 - Bus-Zone & Transformer Differential Protection Relays & CTs

Notes:

a) The P632 relay should be ordered with an extra I/O module. This is required to
allow for the transformer and tapchanger alarms.

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Appendix F Current Transformers for 11kV Switchgear

The following current transformer details are typical values only. The CT specification
shall be determined for specific individual applications and is subject to RailCorp
specification and approval.

RELAY CT
EQUIPMENT SCHEME CT RATIO Notes
TYPE DESIGNATION

MiCOM
11kV Feeder Pilot Wire 300/1 0.05PL50R1.0
P521

MiCOM
11kV Feeder OC & EF 300/150/1 10P50F20
P127

MiCOM
Differential 450/0.577 0.02PL100R3.0 a
P632

33/11kV Tx (6.25 MiCOM

OC & EF 450/1 10P50F20
MVA ) P127

Neutral MiCOM
150/1 10P50F20
leakage P127

11KV/415V Tx MiCOM
Differential 100/1 0.15L50R0.3 a
(1MVA ) P632

Busbar Buszone 600/1 MCAG34 0.03PL120R2.0 b

Bus-tie Cables Buszone 600/1 MCAG34 0.03PL120R2.0 b

Notes:

a) The rated primary current value will depend on the size of the transformer.

b) The rated primary current value will depend on the rating of the busbar.

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Appendix G Protection Relay Identification

Device numbers and functions shall generally be in accordance with IEEE C.37.2. The
detailed implementation shall be as set out below.

Relay Identifier Description

50A Instantaneous Overcurrent Relay (A phase)

50C Instantaneous Overcurrent Relay (C phase)

50/L Instantaneous Overcurrent Relay (A,C & E; feeder)

50/T Instantaneous Overcurrent Relay (A,C & E; transformer)

50/T1 Instantaneous Overcurrent Relay Backup (A,C & E; transformer)

51A Inverse Time Overcurrent Relay (A phase)

51C Inverse Time Overcurrent Relay (C phase)

63 Buchholz Relay

64 Instantaneous Earth Fault Relay

64FL Transformer Frame Leakage Relay

67 Directional Overcurrent Relay

67/L Directional Overcurrent Relay (feeder)

87/B Differential Protective Relay (busbar high impedance)

87/BT Differential Protective Relay (bus-tie cable high impedance)

87/L Differential Protective Relay (feeder - pilot wire scheme)

87/T Differential Protective Relay (transformer)

MTA Multi Trip Automatic Reset Relay

MTM Multi Trip Manual Reset Relay

SRR Send Receive Relay

TBK1, 2 Test Block

TCS Trip Circuit Supervisory Relay

Table 11 - Protection Relay Identification

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Appendix H Standard Test Block Wiring & Input/Output Relay

Configuration
The following test block, protection relay input and output configurations are based on the
majority of existing configurations in the RailCorp network. The configurations do not
determine the requirement for a particular protection function, but detail the test block
connections and output or input relay if that function is to be implemented.

It is not general practice to connect alarms via the test block or connect spare output
relays to the test block. The test block shall be located adjacent to the protection relay it
is associated with.

It is important that new installations comply with these diagrams as they affect the
programming of numerical relays, the testing procedures for periodic maintenance and
the production of standard designs.

Any deviations from the standard configuration must be approved by the Protection
Engineer.

PILOT WIRE PROTECTION:

MBCI+MCRI Check Relays

Relay MMLG01 Incoming Supplies

MBCI RELAY 1-1 contact 2 x 1 Trip +ve

MBCI RELAY 1-1 contact 4 x 3 Pilot Wire Trip
MCRI check contact 6 x 5 MBCI inhibit(11)
MCRI check contact 8 x 7
Pilot 1 MBCI (17) 10 x 9 Pilot 1
Pilot 2 MBCI (18) 12 x 11 Pilot 2
MBCI&MCRI Aux 14 II 13 + 125V dc Aux
MBCI&MCRI Aux 16 x 15 - 125V dc Aux
18 x 17
20 x 19
Ia (MBCI&MCRI) 22 x 21 Ia
Ib (MBCI&MCRI) 24 x 23 Ib
Ic (MBCI&MCRI) 26 x 25 Ic
Io (MBCI&MCRI) 28 x 27 Io

MBCI RELAY OUTPUT RELAYS

RELAY 1-1 PILOT WIRE TRIP

RELAY 1-2 PILOT WIRE TRIP ALARM
RELAY 2-1 INTERTRIP SEND
REALY 2-2 SPARE

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MBOH04 RELAY

Relay MMLG01 Incoming Supplies

MBOH04 contact (1) 2 x 1 Trip +ve

MBOH04 contact (2) 4 x 3 Pilot Wire Trip
6 x 5 Spare
8 x 7 Spare
Pilot 1 MBOH04 10 x 9 Pilot 1
Pilot 2 MBOH04 12 x 11 Pilot 2
14 II 13 Spare
16 x 15 Spare
18 x 17
20 x 19
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

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P543 RELAY

Relay MMLG01 Incoming Supplies

RELAY 1 contact 2 x 1 Trip +ve

RELAY 1 contact 4 x 3 Pilot Wire Trip
Va 6 x 5 Va
Vb 8 x 7 Vb
Vc 10 x 9 Vc
Vn 12 x 11 Vn
TERMINAL J2 14 II 13 + 125V dc Aux Supply
TERMINAL J1 16 x 15 - 125V dc Aux Supply
RELAY 8 contact 18 x 17 Trip +ve
RELAY 8 contact 20 x 19 Breaker FailTrip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:
RELAY 1 PILOT WIRE TRIP
RELAY 2 TCS ALARM
RELAY 3 PILOT WIRE TRIP ALARM
RELAY 4 PILOT WIRE COMMS FAIL ALARM
RELAY 5 SPARE
RELAY 6 BREAKER FAIL ALARM
RELAY 7 SPARE
RELAY 8 BREAKER FAIL TRIP
RELAY 9 SPARE
RELAY 10 SPARE
RELAY 11 SPARE
RELAY 12 SPARE
RELAY 13 SPARE
RELAY 14 SPARE

INPUT RELAYS:
L1 INTERTRIP INITIATE
L2 TCS INPUT
L 3 L16 SPARE

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P521 RELAY

Relay MMLG01 Incoming Supplies

RELAY 1 contact 2 x 1 Trip +ve

RELAY 1 contact 4 x 3 Pilot Wire Trip
6 x 5 Spare
8 x 7 Spare
10 x 9 Spare
12 x 11 Spare
TERMINAL 33 14 II 13 + 125V dc Aux Supply
TERMINAL 34 16 x 15 - 125V dc Aux Supply
RELAY 8 contact 18 x 17 Trip +ve
RELAY 8 contact 20 x 19 Breaker FailTrip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:

RELAY 1 PILOT WIRE TRIP

RELAY 2 TCS ALARM
RELAY 3 PILOT WIRE TRIP ALARM
RELAY 4 PILOT WIRE COMMS FAIL ALARM
RELAY 5 SPARE
RELAY 6 BREAKER FAIL ALARM
RELAY 7 SPARE
RELAY 8 BREAKER FAIL TRIP
INPUT RELAYS:

L1 INTERIPT INITIATE
L2 TCS INPUT
L3 SPARE
L4 SPARE
L5 SPARE

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SIEMENS 7SD610 RELAY

Relay MMLG01 Incoming Supplies

RELAY BO4 contact 2 x 1 Trip +ve

RELAY BO4 contact 4 x 3 Pilot Wire Trip
6 x 5 Spare
8 x 7 Spare
RELAY BO5 contact 10 x 9 Trip +ve
RELAY BO5 contact 12 x 11 Intertrip Trip
TERMINAL F1 14 II 13 + 125V dc Aux Supply
TERMINAL F2 16 x 15 - 125V dc Aux Supply
RELAY BO3 contact 18 x 17 Trip +ve
RELAY BO3 contact 20 x 19 Breaker FailTrip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:

BO1 EA ACCB STATUS

BO2 PILOT WIRE COMMS FAIL ALARM
BO3 BREAKER FAIL ALARM
BO4 PILOT WIRE TRIP
BO5 INTERTRIP RECEIVE

Note: Output replays BO1, BO2 and BO3 are not voltage free contacts. Depending on
the protection requirements additional relays will need to be installed to achieve voltage
free contacts.

The +125V DC for the breaker fail trip is also connected to B01& B02 contacts by internal
relay wiring.

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RECTIFIER OC & EF PROTECTION

P127 RELAY

Relay MMLG01 Incoming Supplies

RELAY 1 contact 2 x 1 Trip +ve

RELAY 1 contact 4 x 3 Overcurrent Trip
RELAY 3 contact 6 x 5 Trip +ve
RELAY 3 contact 8 x 7 Earth Fault Trip
10 x 9 Spare
12 x 11 Spare
TERMINAL 33 14 II 13 + 125V dc Aux Supply
TERMINAL 34 16 x 15 - 125V dc Aux Supply
RELAY 8 contact 18 x 17 Trip +ve
RELAY 8 contact 20 x 19 Breaker FailTrip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:
RELAY 1 OVERCURRENT & EARTH FAULT TRIP
RELAY 2 TCS ALARM
RELAY 3 EARTH FAULT TRIP
RELAY 4 OVERCURRENT ALARM
RELAY 5 EARTH FAULT ALARM
RELAY 6 BREAKER FAIL ALARM
RELAY 7 SPARE
RELAY 8 BREAKER FAIL TRIP

INPUT RELAYS:
INPUT L1 SPARE
INPUT L2 SPARE
INPUT L3 SPARE
INPUT L4 TCS
INPUT L5 TIMER INITIATE
INPUT L6 SPARE
INPUT L7 SPARE

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RECTIFIER OC & EF PROTECTION

P124 RELAY (DUAL POWERED VERSION)

Relay MMLG01 Incoming Supplies

RELAY 1 contact 2 x 1 Trip +ve

RELAY 1 contact 4 x 3 Overcurrent Trip
RELAY 3 contact 6 x 5 Trip +ve
RELAY 3 contact 8 x 7 Earth Fault Trip
10 x 9 Spare
12 x 11 Spare
TERMINAL 33 14 II 13 ac Aux Supply
TERMINAL 34 16 x 15 ac Aux Supply
RELAY 6 contact 18 x 17 Trip +ve
RELAY 6 contact 20 x 19 Breaker FailTrip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:
RELAY 1 OVERCURRENT & EARTH FAULT TRIP
RELAY 2 TCS ALARM
RELAY 3 EARTH FAULT TRIP
RELAY 4 OVERCURRENT & EARTH FAULT ALARM
RELAY 5 EARTH FAULT ALARM
RELAY 6 BREAKER FAIL ALARM

INPUT RELAYS:
INPUT L1 SPARE
INPUT L2 SPARE
INPUT L3 SPARE
INPUT L4 TCS
INPUT L5 SPARE
INPUT L6 SPARE
INPUT L7 SPARE

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RECTIFIER OC & EF PROTECTION

MCAG33 RELAY

Relay MMLG01 Incoming Supplies

MCAG trip contact 2 x 1 MVAJ13 Trip +ve

MCAG trip contact 4 x 3 MVAJ13 Trip
Spare trip contact 6 x 5 Spare trip contact
Spare trip contact 8 x 7 Spare trip contact
Spare 10 x 9 Spare
Spare 12 x 11 Spare
Spare 14 II 13 Spare
Spare 16 x 15 Spare
Spare 18 x 17 Spare
Spare 20 x 19 Spare
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

RELAY CONTACTS:

A contacts: terminals 1 & 3 : trip

2 & 4 SCADA alarm

E/F contacts: terminals 5 & 7 : trip

6 & 8 SCADA alarm

C contacts: terminals 9 & 11 : trip

10 & 12 SCADA alarm

Notes:

1. A & C phase trip contacts are connected in parallel at the relay terminals.

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RECTIFIER TRANSFORMER FRAME LEAKAGE PROTECTION

MCAG14 RELAY

Relay MMLG01 Incoming Supplies

MCAG trip contact 2 x 1 Trip +ve

MCAG trip contact 4 x 3 Trip
Spare trip contact 6 x 5 Spare trip contact
Spare trip contact 8 x 7 Spare trip contact
Spare 10 x 9 Spare
Spare 12 x 11 Spare
Spare 14 II 13 Spare
Spare 16 x 15 Spare
Spare 18 x 17 Spare
Spare 20 x 19 Spare
IFL 22 x 21 IFL
IFL 24 x 23 IFL
Spare 26 x 25 Spare
Spare 28 x 27 Spare

RELAY CONTACTS:

MCAG14 contacts: terminals 1 & 3: TRIP

2 & 4: SCADA alarm

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33/11kV TRANSFORMER OC & EF PROTECTON

P127 RELAY

Relay MMLG01 Incoming Supplies

RELAY 7 contact 2 x 1 Trip +ve

RELAY 7 contact 4 x 3 Overcurrent Trip
RELAY 3 contact 6 x 5 Trip +ve
RELAY 3 contact 8 x 7 Earth Fault Trip
10 x 9 Spare
12 x 11 Spare
TERMINAL 33 14 II 13 + 125V dc Aux Supply
TERMINAL 34 16 x 15 + 125V dc Aux Supply
RELAY 8 contact 18 x 17 Trip +ve
RELAY 8 contact 20 x 19 Breaker Fail Trip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:

RELAY 1 NOT AVAILABLE *

RELAY 2 TCS ALARM
RELAY 3 EARTH FAULT TRIP
RELAY 4 OVERCURRENT ALARM
RELAY 5 EARTH FAULT ALARM
RELAY 6 BREAKER FAIL ALARM
RELAY 7 OVERCURRENT TRIP
RELAY 8 BREAKER FAIL TRIP

INPUT RELAYS:

INPUT L1 SPARE
INPUT L2 SPARE
INPUT L3 SPARE
INPUT L4 TCS
INPUT L5 SPARE
INPUT L6 SPARE
INPUT L7 SPARE

* THE BREAKER FAIL FUNCTION OF THE RELAY IS INITIATED INTERNALLY BY

RELAY 1. HENCE RELAY 1 IS PROGRAMMED TO BE ENERGISED FOR EITHER AN
OVERCURRENT OR EARTH FAULT TRIP. HOWEVER, IT IS NOT CONNECTED
EXTERNALLY AS AN OVERCURRENT TRIP IS REQUIRED TO ENERGISE AN MTA
RELAY AND THE EARTH FAULT TRIP IS REQUIRED TO ENERGISE AN MTM RELAY.

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NEUTRAL LEAKAGE PROTECTON

P127 RELAY

Relay MMLG01 Incoming Supplies

RELAY 1 contact 2 x 1 Trip +ve

RELAY 1 contact 4 x 3 Neutral Leakage Trip
6 x 5 Spare
8 x 7 Spare
10 x 9 Spare
12 x 11 Spare
TERMINAL 33 14 II 13 + 125V dc Aux Supply
TERMINAL 34 16 x 15 + 125V dc Aux Supply
RELAY 8 contact 18 x 17 Trip +ve
RELAY 8 contact 20 x 19 Breaker Fail Trip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:

RELAY 1 NEUTRAL LEAKAGE TRIP

RELAY 2 TCS ALARM
RELAY 3 SPARE
RELAY 4 NEUTRAL LEAKAGE ALARM
RELAY 5 SPARE
RELAY 6 BREAKER FAIL ALARM
RELAY 7 SPARE
RELAY 8 BREAKER FAIL TRIP

INPUT RELAYS:

INPUT L1 SPARE
INPUT L2 SPARE
INPUT L3 SPARE
INPUT L4 TCS
INPUT L5 SPARE
INPUT L6 SPARE
INPUT L7 SPARE

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33/11kV TRANSFORMER (11KV SIDE)

OC & NEUTRAL LEAKAGE PROTECTON

P127 RELAY

Relay MMLG01 Incoming Supplies

RELAY 7 contact 2 x 1 Trip +ve

RELAY 7 contact 4 x 3 Overcurrent Trip
RELAY 3 contact 6 x 5 Trip +ve
RELAY 3 contact 8 x 7 Neutral leakage Trip
In 10 x 9 In
In 12 x 11 In
TERMINAL 33 14 II 13 + 125V dc Aux Supply
TERMINAL 34 16 x 15 + 125V dc Aux Supply
RELAY 8 contact 18 x 17 Trip +ve
RELAY 8 contact 20 x 19 Breaker Fail Trip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:

RELAY 1 SPARE
RELAY 2 TCS ALARM
RELAY 3 NEUTRAL LEAKAGE TRIP (TO MTA RELAY)
RELAY 4 OVERCURRENT ALARM
RELAY 5 NEUTRAL LEAKAGE ALARM
RELAY 6 BREAKER FAIL ALARM
RELAY 7 OVERCURRENT TRIP (TO 11KV ACCB)
RELAY 8 BREAKER FAIL TRIP

INPUT RELAYS:

INPUT L1 SPARE
INPUT L2 SPARE
INPUT L3 SPARE
INPUT L4 TCS
INPUT L5 SPARE
INPUT L6 SPARE
INPUT L7 SPARE

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11kV DISTRIBUTION TRANSFORMER OC & EF PROTECTION

VIP300LL RELAY

Relay MMLG01 Incoming Supplies

TERMINAL 15 2 x 1 Trip -ve

TERMINAL 16 4 x 3 Trip +ve
6 x 5 Spare
8 x 7 Spare
10 x 9 Spare
12 x 11 Spare
14 II 13 Spare
16 x 15 Spare
TERMINAL 12 18 x 17 Ia
TERMINAL 8 20 x 19 Ia
TERMINAL 11 22 x 21 Ib
TERMINAL 6 24 x 23 Ib
TERMINAL 10 26 x 25 Ic
TERMINAL 4 28 x 27 Ic

11kV DISTRIBUTION TRANSFORMER OC & EF PROTECTION

VIP300LL RELAY

Relay (x4 range 50-200A) MMLG01 Incoming Supplies

TERMINAL 15 2 x 1 Trip -ve

TERMINAL 16 4 x 3 Trip +ve
6 x 5 Spare
8 x 7 Spare
10 x 9 Spare
12 x 11 Spare
14 II 13 Spare
16 x 15 Spare
TERMINAL 12 18 x 17 Ia
TERMINAL 7 20 x 19 Ia
TERMINAL 11 22 x 21 Ib
TERMINAL 5 24 x 23 Ib
TERMINAL 10 26 x 25 Ic
TERMINAL 3 28 x 27 Lc

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FEEDER DOC & DEF PROTECTION

P127 RELAY

Relay MMLG01 Incoming Supplies

RELAY 1 contact 2 x 1 Trip +ve

RELAY 1 contact 4 x 3 Trip
Va 6 x 5 Va
Vb 8 x 7 Vb
Vc 10 x 9 Vc
Vn 12 x 11 Vn
TERMINAL 33 14 II 13 + 125V dc Aux Supply
TERMINAL 34 16 x 15 - 125V dc Aux Supply
RELAY 8 contact 18 x 17 Trip +ve
RELAY 8 contact 20 x 19 Breaker Fail Trip
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:

RELAY 1 OVERCURRENT & EARTH FAULT TRIP

RELAY 2 TCS ALARM
RELAY 3 SPARE
RELAY 4 OVERCURRENT ALARM
RELAY 5 EARTH FAULT ALARM
RELAY 6 BREAKER FAIL ALARM
RELAY 7 INTERTRIP SEND (IF REQUIRED)
RELAY 8 BREAKER FAIL TRIP

INPUT RELAYS:

INPUT L1 SPARE
INPUT L2 SPARE
INPUT L3 SPARE
INPUT L4 TCS
INPUT L5 SPARE
INPUT L6 SPARE
INPUT L7 SPARE

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FEEDER DOC & DEF PROTECTION

KCEG142 RELAY

Relay MMLG01 Incoming Supplies

KCEG142 trip contact 2 x 1 52 Trip +ve

KCEG142 trip contact 4 x 3 52 Trip
Va 6 x 5 Va
Vb 8 x 7 Vb
Vc 10 x 9 Vc
Vn 12 x 11 Vn
KCEG142 Aux 14 II 13 + 125V dc Aux
KCEG142 Aux 16 x 15 - 125V dc Aux
KCEG142 ACCB fail trip
18 x 17 ACCB/fail trip +ve
contact
KCEG142 ACCB fail trip
20 x 19 ACCB/fail multitrip
contact
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS:

RELAY 0 SPARE
RELAY 1 BREAKER FAIL ALARM
RELAY 2 SPARE
RELAY 3 OVERCURRENT & EARTH FAULT TRIP
RELAY 4 OVERCURRENT ALARM
RELAY 5 EARTH FAULT ALARM
RELAY 6 SPARE
RELAY 7 BREAKER FAIL TRIP

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TRANSFORMER DIFFERENTIAL PROTECTION

P632/MBCH RELAY

Relay MMLG01 Incoming Supplies

P632/MBCH trip contact 2 x 1 MVAJ Trip +ve

P632/MBCH trip contact 4 x 3 MVAJ Trip
Spare 6 x 5 Spare
Ia (delta connected C.Ts) 8 x 7 Ia
Ib (delta connected C.Ts) 10 x 9 Ib
Ic (delta connected C.Ts) 12 x 11 Ic
P632/MBCH Aux 14 II 13 + 125V dc Aux
P632/MBCH Aux 16 x 15 - 125V dc Aux
Spare 18 x 17 Spare
Spare 20 x 19 Spare
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

OUTPUT RELAYS (P632):

TAP CHANGER PRESSURE SWITCH

K901 TX DIFFERENTIAL TRIP K701
ALARM
K902 RELAY HEALTHY K702 BREAKER FAIL ALARM
K903 BREAKER FAIL TRIP K703 TAP CHANGER OIL SURGE ALARM
K904 TX DIFFERENTIAL TRIP ALARM K704 SPARE
K905 TX BUCHHOLZ GAS ALARM K705 SPARE
K906 TX BUCHHOLZ OIL ALARM K706 SPARE
K907 TAP CHANGER ALARM K707 SPARE
K908 TCS ALARM K708 SPARE

INPUT RELAYS (P632):

U901 TAP CHANGER OIL SURGE OPERATION

U902 TX BUCHHOLZ OIL SURGE OPERATION
U903 TX BUCHHOLZ GAS OPERATION
U904 TAP CHANGER ALARM

U701 TAPCHANGER PRESSURE SWITCH

U702 TCS
U703 SPARE
U704 SPARE
U705 SPARE
U706 SPARE

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DIRECTIONAL OC/E FEEDER PROTECTION:

RELAY: MCGG52 + METI

Relay MMLG01 Incoming Supplies

MCGG trip contact 2 x 1 52 Trip +ve

MCGG trip contact 4 x 3 52 Trip
Va 6 x 5 Va
Vb 8 x 7 Vb
Vc 10 x 9 Vc
METI Aux 12 x 11
MCGG &METI Aux 14 II 13 + 125 V dc Aux
MCGG Aux 16 x 15 - 125 V dc Aux
Vo1 (open delta voltage) 18 x 17 Vo1
Vo2 (open delta voltage) 20 x 19 Vo2
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

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FEEDER PROTECTION, OVERCURRENT & EARTH FAULT

RELAY: MCGG52/82

Relay MMLG01 Incoming Supplies

MCGG trip contact 2 x 1 52 Trip +ve

MCGG trip contact 4 x 3 52 Trip
Spare 6 x 5 Spare
Spare 8 x 7 Spare
Spare 10 x 9 Spare
Spare 12 x 11 Spare
MCGG Aux 14 II 13 + 125 V dc Aux
MCGG Aux 16 x 15 - 125 V dc Aux
Spare 18 x 17 Spare
Spare 20 x 19 Spare
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

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BUS TIE / BUS ZONE PROTECTION

MCAG34 RELAY

Relay MMLG01 Incoming Supplies

MCAG trip contact 2 x 1 Trip +ve

MCAG trip contact 4 x 3 Trip
Spare trip contact 6 x 5 Spare trip contact
Spare trip contact 8 x 7 Spare trip contact
Spare 10 x 9 Spare
Spare 12 x 11 Spare
Spare 14 II 13 Spare
Spare 16 x 15 Spare
Spare 18 x 17 Spare
Spare 20 x 19 Spare
Ia 22 x 21 Ia
Ib 24 x 23 Ib
Ic 26 x 25 Ic
Io 28 x 27 Io

RELAY CONTACTS:

A contacts: terminals 1 & 3 : trip

2 & 4 SCADA alarm

B contacts: terminals 5 & 7 : trip

6 & 8 SCADA alarm

C contacts: terminals 9 & 11 : trip

10 & 12 SCADA alarm

Notes:

1. A, B &, C phase trip contacts are connected in parallel at the relay terminals.

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RECTIFIER LOCAL BACKUP PROTECTION

MVTT14 + MCTI39 RELAYS

Relay MMLG01 Incoming Supplies

MCTI trip contact 2 x 1 52 Trip +ve

MCTI trip contact 4 x 3 52 Trip
MCTI current check 6 x 5 CB/fail trip +ve
MCTI current check 8 x 7
lLocal bu +ve 10 x 9 CAG33 contact
MVTT start 12 x 11 CAG33 contact
Local bu +ve 14 II 13 + 125V dc local bu Aux
Local bu -ve 16 x 15 - 125V dc local bu Aux
MVTT Breaker fail trip
18 x 17
contact
MVTT Breaker fail trip
20 x 19 CB/fail multitrip
contact
MCTI Ia 22 x 21 Ia
MCTI Ib 24 x 23 Ib
MCTI Ic 26 x 25 Ic
MCTI Io 28 x 27 Io

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Protection System Requirements for the High Voltage Network EP 19 00 00 02 SP

Appendix I Voltage and Current Transducers

Transducers that are to be used to provide the SCADA system with current and voltage
information relating to the high voltage network shall have the following general
characteristics:

Output of 020mA
Mean sensing
Self powered

The following transducer is approved for connection in the protection current transformer
circuit.

Areva Istat 300; Type 3CAEA513AA (for CTs with 1A secondaries)

Areva Istat 300; Type 3CAEA55GKA (for CTs with 5A secondaries)

The following transducer is approved for connection in the voltage transformer circuit.

Areva Istat 400; Type I4VAEA0-125, (nominal input range of 0-125V ac to measure a
110V ac voltage transformer output, usually measuring the voltage between A &
C).

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Appendix J Pilot Wire Schemes

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Appendix K Auto Re-close on High Voltage Feeders

The RailCorp re-closure policy is as follows:

In general, one auto re-close in 5 seconds by SCADA (ie the master station initiates the
auto re-close if all the requirements are met).

This policy applies to the following:

2kV, 11kV, 33kV 66kV aerial lines

11kV, 33kV 66kV cables, no auto re-close
2kV signalling cables do have auto re-close because of the criticality of maintaining
the supply and often the fault blows clear.
A feeder that is partially cable and partially aerial line is treated as aerial line.

During periods of total fire ban the auto re-close is inhibited on 33kV and 66kV feeders
that traverse areas considered to be a bush fire risk . This is a master station function
initiated by the ESO's.

Auto re-close is also automatically inhibited for 10 minutes after a close control.

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Protection System Requirements for the High Voltage Network EP 19 00 00 02 SP

Appendix L Protection SCADA Alarms

The following is a list of typical protection alarms required. The exact alarm requirement
depends on the following factors:

Type of relay
Capacity of RTU
Function of relay
Value adding of the alarm information to the EOC operator and RailCorp Protection
Engineer.

Refer to EP11 00 00 07 SP Design Technical Reviews for Electrical SCADA Equipment

for further guidance and a typical example of a SCADA I/O schedule.

In many existing locations some of the protection alarms (eg. TCS) are connected in
parallel for each piece of equipment to give one general alarm. This was due to the
limitations on the quantity of alarms that could be connected to the RTU at the time of
installation.

PROTECTION SCADA ALARMS

ORIGIN OF ALARM SCADA ALARM NAME COMMENTS
ACCB SpringCharged
LowGas The number of alarm stages will depend on
LowGasLockOut the ACCB being installed.
MotorSupply
MotorTrouble

PROTECTION RELAY DirectionProtectionA

DirectionProtectionB
DirectionProtectionC
DirectionRelayFail
DirectionalDCSupply
PilotWireTripA
PilotWireTripB
PilotWireTripC
BrokenConductorA
BrokenConductorB
BrokenConductorC
PilotWireComms
PilotWireRelayFail
RelayCommFail
OverCurrentA
OverCurrentB
OverCurrentC
EarthLeakage
InstOverCurrentA
InstOverCurrentB
InstOverCurrentC
Inst_OC/ELtrip
OverCurrentRelayFail
BreakerFail
NeutralLeakageProtection
IntertripReceive

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PROTECTION SCADA ALARMS

ORIGIN OF ALARM SCADA ALARM NAME COMMENTS
IntertripSend
BusZone1
BusZone2
BusZone3
BusZoneRelayFail
DifferentialProtectionA
DifferentialProtectionB
DifferentialProtectionC
DifferentialRelayFail
TripCircuitSupervision
SFORMER BuchholzGas
BuchholzOil
TCBuchholzGas
TCBuchholzOil
TCFail
TCLowLimit
These alarms originate from the transformer
TCHighLimit
tap changer.
TCControlSupply
TCInProgress
TCIncomplete
TCRefSupplyAlarm
TemperatureAlarm This alarm originates from the temperature
indicators on the transformer. There could
possibly be several stages.

VOLTAGE PhaseFailure This alarm originates from a dedicated phase

TRANSFORMER failure relay connected to the output of the VT.
DirectionalAlarm This alarm originates from a LV circuit breaker
that supplies the voltage to the specific
directional protection relay.
DCCB Frame Leakage DCFrameLeakage
BATTERY CHARGER BattChargerAC
BattUnderVolts These alarms originate from the battery
charger and the exact alarms available will
BattOverVolts
depend on the battery charger.
BattConnected

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Appendix M Implementation Of SCADA Alarms & Control

The SCADA alarms and control to and from equipment can be implemented by hard
wiring or using a high level interface such as a serial link.

Numerical protection relays can be used to convey the information by using discrete
output relays or via serial links. However certain information is critical for system
operation and must be independent on the protection relay or communication link to the
RTU.

The following list details the SCADA alarms and control that are required to be hard wired
to the RTU.

ACCB control (both open and close)

ACCB indication (both open and closed)
ACCB DISCONNECTOR/ISOLATOR indication (all positions)*
EARTH SWITCH indication (both open and closed)*
Tapchanger control
Battery Charger alarms
Protection relay watchdog alarms
Trip Circuit Supervision (TCS), where provided by a dedicated TCS relay.
Analogues (current and voltage)
Phase failure relay

* If all circuit breakers on a switchboard are not fitted with numerical relays having
adequate RS485 communications to the RTU

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Appendix N Typical ACCB Auxiliary Supply Arrangement

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Protection System Requirements for the High Voltage Network

RailCorp Engineering Standard Electrical
125V DC DISTIBUTION 125V DC DISTIBUTION
BOARDNo.1 HV SWITCHBOARD BOARDNo.2

CIRCUITS COMMON TO PANELNo.1 PANEL r.;o .2 PANEi..No.J

ENTIRE SWITCHBOARD

ILISor BZ PRlM Rl.Y PRltl. Rl,.Y r"'11tL 1 I

--- ~ r -- - -B-;
i

EEE i
I

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UNCONTROLLED WHEN PRINTED

- - - - -, : : I ! !i i
: : MOTOR I MOl OR MOTOR I I
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~---- --- - - ----- ----- - - -- ----- -- - - - -- -- - - ----- --~

=
1. FOR SIMPllCITY OF DIAGRAM , Ot"i.Y ~ ve FUSES SHOWN
2. SUBMAlNS FOR f t-iE SAME HV PANEL ARE REQUIRED TO
~
PRIM Rl.Y: PRIMARY PROTECTION RELAY
au RlY: BACKUP PROTECTION RELAY
.,......,.~ ARRANGEMENT OF DC
AUXILIARY SYSTEMS

BE RUN VIA l NOEPENOAtn ROUTES. IL!S; INTELLIGENT LIGHT INFORMATION SYS TEM & !:E R.'lilCo rp 2 BATTERY SYSTEM
3. ORIGlN Of 125V SUPPlY FOR SCAOAALARMS DEPENDS Qt' IGIS: 111/TElllGENT GA.5 INFORMATION SYSTEM
ORIGIN Of RTU SUPPLY. OZ: TRADITIONAL BUSZONE PROTECTION tC.IS

EP 19 00 00 02 SP
E n g i nuurlng Sk111d{lrd~ tmd SorvlCOG,
E l t,>ctric.al. 17110/2005 I V(ll:SION 10
Page 61 of 71

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RailCorp Engineering Standard Electrical
Protection System Requirements for the High Voltage Network EP 19 00 00 02 SP

Appendix O Protection Relay Labelling Guidelines

The following rules apply to the labelling of protection relays and associated auxiliary
relays:

Location of Labels:

Labels should be located above the relay. If this is not possible, then they
should be located directly below the relay.

Colour of Labels:

All protection relays labels shall have black writing on a yellow background.
All auxiliary relays (such as multi-trip relays) shall have black writing on a white
background.

Format

To keep the length of labels to a minimum, abbreviations shall be used for the
protection functions. The valid abbreviations are detailed in Table 12.
All labels are to be in CAPITALS (except for abbreviations such as Tx & kV).
The description of equipment shall be consistent with terminology as used in the
AC operating diagrams. This is summarised below:
FEEDERS: Feeder ID ;
Where Feeder ID is the unique 3 digit identification assigned to each high
voltage feeder.
TRANSFORMERS: Unit ID + voltage ratio + Tx ;
Where Unit ID is the identification given where there are multiple transformers
(eg. No.1, No.2 etc). voltage ratio is the voltage ratio of the transformer
usually expressed in kV (eg. 33/11kV, 66/33kV).
RECTIFERS: Unit ID + RECTIFIER
Where Unit ID is the identification given where there are multiple rectifiers (eg.
No.1, No.2 etc).

Content:

FIRST LINE OF LABEL:

The following sequence should be used to construct a label:

i) Equipment being Protected/Monitored

eg. N
o.1 RECTIFIER
BUS ZONE
792
No.2 33/11kV Tx

ii) Type of Protection

eg. DOC & DE RELAY

PW RELAY
A DOC RELAY
A OC RELAY
FL RELAY
Tx OC RELAY
Tx DIFF RELAY

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iii) Make of Relay in Brackets.

eg. (HMB4), (P521), (HO4)

(CDD31), (P127), (CRP7), (CR LE)
(P632), (KBCH), (DDT)

iv) Pointer to Relay (if needed)

eg.

EXAMPLES OF LABELS:

798 DOC & DE RELAY (P127)

798 PW RELAY (P521)

No.1 RECT IOC & IE RELAY (MCAG33)

No.1 RECT IOC & IE BACKUP RELAY (P127)

TRIP CCT 1 TCS RELAY(1TM10)

No.1 33/11kV TxDIFF RELAY (P632)

No.1 33/11kV Tx OC & E RELAY (P127)

1-2 BZT RELAY (MCAG34)

1-2 BZT MTM RELAY (MVAJ13)

No.1 33/11kV Tx MTA RELAY (MVAJ11)

No.1 SECTION BZ MTM RELAY (MVAJ13)

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PROTECTION FUNCTION ABBREVIATION

ARC DETECTION AD
BUCHHOLZ B
BREAKER FAIL BF
BLOCKING RELAY BRly
BACKUP BU
BUS ZONE BZ
BUS ZONE TIE BZT
DIRECTIONAL EARTH FAULT DE
DIRECTIONAL INSTANTANEOUS OVERCURRENT DIOC
DIRECTIONAL OVERCURRENT DOC
EARTH FAULT E
DCCB FRAME LEAKAGE FLDC
AC FRAME LEAKAGE FL
RECTIFIER FRAME LEAKAGE FLR
INSTANTANEOUS EARTH LEAKAGE IE
INTELLIGENT GAS INFORMATION SYSTEM IGIS
INTELLIGENT LIGHT INFORMATION SYSTEM ILIS
INSTANTANEOUS OVERCURRENT IOC
INTERTRIP IT
INSTANTANEOUS & TIME DELAY OVERCURRENT ITOC
MUTI TRIP RELAY AUTOMATIC RESET MTA
MULTI TRIP RELAY MANUAL RESET (HAND) MTM
NEUTRAL LEAKAGE NL
OVERCURRENT OC
LOW OIL LO
OVERCURRENT & RESIDUAL EARTH FAULT INVERSE TIME ORET
PRESSURE SWITCH PS
PILOT WIRE PW
DC REVERSE CURRENT RC
TRANSFORMER DIFFERENTIAL TxDIFF
TRANSFORMER WINDING TEMPERATURE WT
TRIP CIRCUIT SUPERVISION TCS
TRIP SUPPLY SUPERVISION TSS

Table 12 - Protection Function Abbreviations

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Appendix P Standard Current Transformer Configurations

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RailCorp

Protection System Requirements for the High Voltage Network

RailCorp Engineering Standard Electrical
.ti cih.~
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TRIP DIRECTION

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EP 19 00 00 02 SP
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ARRANGEMENT

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Page 66 of 71

ReLAVI
SCMEME PROTECTION
Version 4.1

Engineering S1andards and Services,

E tcctricaf Systoms
I DATE
26110/2000 IVERSION 3.0
Issued June 2012
RailCorp

Protection System Requirements for the High Voltage Network

RailCorp Engineering Standard Electrical
.., P> ~
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SUBSTATIONA _:.~""-:..::..~~~+-~~-F4+-~~~ BPHASE SUBSTATION B
BUSBARS BUS BARS
C PH- OP.....
UNCONTROLLED WHEN PRINTED

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EP 19 00 00 02 SP
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Page 67 of 71

F!EtAY/ MiCOM P521 - PILOT WIRE

SOEllE SCHEME
Version 4.1

E ngineering Standards and Services,

E loctrlcal Systoms DAT!C 26110!2006 VERSION 3.0
RailCorp Engineering Standard Electrical
Protection System Requirements for the High Voltage Network EP 19 00 00 02 SP

Appendix Q Metering Requirements For Bulk Supply Points

The following metering requirements are applicable to a RailCorp substation with indoor
HV switchgear (AREVA/Schneider WSA GIS switchgear). These requirements are
correct at the time of publication of this standard and should be confirmed with the
relevant Supply Authority.

The requirements are based on the following documents:

Ausgrid: Metering Installations part A, Document ES3, September 2009

Endeavour Energy: Metering Design Instruction, Document No: MET 0002 (amendment
0)

Metering Requirements for Bulk Supply Points Interfacing with Ausgrid or

Endeavour Energy.

VOLTAGE TRANSFORMERS:

Dedicated winding required (1 per phase), class 0.5 and 50VA for Ausgrid, class 0.2
and 100VA for Endeavour Energy, form factor of 1.9/30s. Associated LV circuit
breaker installed on the output with auxiliary contact of circuit breaker connected to
SCADA.
Warning label required adjacent to VT isolating handle (eg. "WARNING - VT
SUPPLIES 7XX REVENUE METERING ").

CURRENT TRANSFORMERS:

Dedicated set of metering class CT's with following parameters:

Ratio: identical to protection CTs on same feeder

Designation: 15VA CLASS 0.5S,

Thermal limit current =2.0A,

Rated short-time current 31.5kA for 3s

The CT's are required to be positioned adjacent to the metering CT's used for
RailCorp check metering.
Additional secondary wiring and associated CT links are required for connection to the
new CTs

CURRENT TRANSFORMER & VOLTAGE TRANSFORMER TEST RESULTS

The manufacturers test reports for the voltage transformers and current transformers are
required to be submitted to RailCorp.

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SECONDARY WIRING FROM 33KV SWITCHBOARD TO METER PANEL

The CT & VT secondary wiring is required to be run in separate conduits to the new
meter panel.
The CT secondary wiring is to be a multi-core cable PVC/PVC minimum size of
2.5mm2
The VT secondary wiring is to be a multi-core cable PVC/PVC minimum size
of 2.5mm2 for Ausgrid and 4mm2 for Endeavour Energy.

240V AC SUPPLY TO METERING PANEL

Dedicated 240Vac supply from the 415V DB required to be run in separate conduit to
the metering panel.
The 415V DB to have appropriate identification label and additional label "DO NOT
TURN OFF" or similar adjacent to circuit breaker.

METERING PANEL

The proposed location of the metering panel has to be approved by RailCorp prior to
installation. The metering panel should be located on the external wall of the
substation.
The metering panel (including equipment) should be purchased directly from the
Supply Authority where available.

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Appendix R Current Transformer, Voltage Transformer and

General Protection - Wire Identification Code

Letter Circuit function Wire numbers

Current transformers for primary protection,
A
excluding overcurrent
B Current transformer for busbar protection
10-29 Red phase
30-49 White phase
Current transformers for overcurrent protection
C 50-69 Blue phase
(including combined earth-fault and instruments)
70-89 Residual circuits and neutral
current transformers
Current transformers for instruments, metering 90 Earth wires directly connected to the
D
voltage control earth bar
Reference voltage of instruments, metering and
E 91-99
protection
K Closing and tripping control circuits Any number from 1 upwards
Alarms and indications initiated by auxiliary
switches and relay contact, excluding those for
L Any number from 1 upwards
remote selective control and for general
indication equipment
Pilot conductors (including directly associated
connections) between panels, independent of
T Any number from 1 upwards
the distance between them, for pilot-wire
protection, for inter-tripping or for both

Notes:

If more numbers are required, add multiples of one hundred, e.g. 10-29 may be extended to 110-129, 210-229.

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Appendix S Protection Non-Compliances Particular to the ECRL

Project
This appendix details known design issues relating to the protection schemes and
equipment installed in the ECRL project that do not comply with the general requirements
of this standard.

These arrangements have been accepted for the ECRL project only.

11kV Protection

Bus-zone protection not installed on the 11kV switchboards, (blocking scheme

installed in lieu).
Pilot wire protection not installed on the 11kV feeders.
Multi-trip relays not used.
Dual trip coils not installed.
Test blocks not wired in accordance with standard configuration.
Protection relays not programmed with standard configuration.

33kV Protection

Multi-trip relays not used on the 33/11kV transformer protection (pushbutton installed
to reset latched P632 output relays).
Dual trip coils not installed.
Test blocks not wired in accordance with standard configuration.
Protection relays not programmed with standard configuration.

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