Calculation

Copy No.

A coloured number in this space indicates that this document is controlled

Discipline

Electrical Engineering Specification

Category

Fault Protection

Title

Protection System Requirements for the High Voltage Network Reference Number

EP 19 00 00 02 SP Version

3.4

Date of Issue

JUNE 2007

Status

Approved

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

JUNE 2007 Version 3.4 © RailCorp of 85

DISCLAIMER

RailCorp has used its best endeavours to ensure that the content, layout and text of this document are accurate, complete and suitable for it’s stated purpose. It makes no warranties, express or implied, that compliance with the contents of this document shall be sufficient to ensure safe systems of work or operation.

RailCorp will not be liable to pay compensation in respect of the content or subsequent use of this document for any other purpose than its stated purpose or for any purpose other than that for which it was prepared except where it can be shown to have acted in bad faith or there has been wilful default.

DOCUMENT APPROVAL

The technical content of this document has been approved by the relevant RailCorp engineering authority and has also been endorsed by the RailCorp Configuration Management Committee directly or as delegated through the conditions of the Configuration Management Policy.

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The information in this document is Copyright protected. Apart from the reproduction without alteration of this document for personal use, non-profit purposes or for any fair dealing as permitted under the Copyright Act 1968, no part of this document may be reproduced, altered, stored or transmitted by any person without the prior written consent of RailCorp.



About This Standard This document covers the Protection System requirements for the RailCorp High Voltage AC Network for 11kV, 33kV, 66kV and 132kV system voltages. The scope of this publication does not currently include specific requirements for the high voltage AC network at 2kV. This will be incorporated in a future revision of this specification.

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.



Version History Version 2.0

The changes in this document are:

• Reformatting of the document

• Changes to organisational names and position titles to reflect the formation of Rail Infrastructure Corporation

Version 3.0

• Major expansion of information in the previous version.

Version 3.1

• Correction to pilot wire relay model.

• Transformer differential relay types modified.

• Alternative busbar fault detection system added.

• Details of equipment connected to ACCB trip coils added.

• 33kV bus-zone CT ratio changed.

Version 3.2

• Organisation change from Rail Infrastructure Corporation to RailCorp.

• Clarifications to breaker fail operation implementation with pilot wire schemes.

• Auto reclose policy for high voltage feeders added.

• Details of earth fault operation added for rectifier transformer protection and clarification to associated trip coil operation.

• Details of requirements when there are two battery systems and typical auxiliary supply to HV ACCB’s added.

• MTM relay requirements added.

• Siemens 7D6S10 pilot wire relay added as an approved relay.

• Details of MBCI02 relay added.

• Detailed listing of SCADA alarms added.

• Additional protection relay identifications added.

• Standard test block configuration amended and standard relay input and output configuration added.



Version 3.3

• Requirement for TCS to be fitted to existing equipment added when new protection

schemes are interfacing with existing switchgear.

• 11kV feeder protection requirements added.

• Requirements for breaker fail implementation added when installing electronic protection relays in an existing substation.

• Details of requirements for the VT supply to protection relays added.

• Requirements for “CLOSE INHIBIT” amended.

• Protection and auxiliary relay labelling guidelines added.

• Details of protection requirements for use on 11kV distribution transformers (up to 800kVA) added.

• Correction made to P127 output relays for system transformers and rectifier transformers.

• P632 output relay functions amended.

• Details of test block and relay configuration added for Siemens 7SD610 relay.

• Details of test block and configuration added for VIP35 relay.

• Details of SCADA alarms and control that are required to be hard wired added to Appendix K.

Version 3.4

• Requirement for position of EARTH SWITCH, DISCONNECTOR & ACCB to be supplied as an input to P127relays removed.

• Breaker fail implementation added when a dedicated ACCB is not available.

• Standard current transformer configuration diagrams added as an appendix.

• Transducer model numbers detailed for 1A and 5A current transformers and voltage transducer model number expanded.

• Details of test block and configuration added for VIP300LL relay

• Protection requirement for 11kV equipment modified.

• Specific protection documentation requirements added.

• ECRL protection no-compliances added as an appendix.

• Current transformers for 11kV switchboards added.



Contents 1 Scope and Application .................................................................... 10

2 Normative References..................................................................... 11

2.1 International Standards.............................................................................. 11 2.2 Australian Standards.................................................................................. 11 2.3 RailCorp Documents .................................................................................. 11 2.4 Industry Publications ................................................................................. 12

3 Definitions and Abbreviations........................................................ 13

4 General Protection Philosophy ...................................................... 15

4.1 General ........................................................................................................ 15 4.2 Protection Settings..................................................................................... 15 4.3 Grading ........................................................................................................ 15

5 Specific Protection Equipment Requirements .............................. 17

5.1 Protection Equipment Design Principles - All New HV Switchgear ....... 17 5.2 Interfacing New Protection Schemes With Existing Equipment ............ 18

5.2.1 Multiple Use of Current Transformers 18 5.2.2 Trip Circuit Supervision 18 5.2.3 Breaker Fail 18 5.2.4 Inter-trip 18

5.3 Current Transformers (CT) ........................................................................ 18 5.3.1 General Requirements 18 5.3.2 Additional Requirements for CT’s with a Rated Secondary Current of 1 Amp.19 5.3.3 Multiple Ratio Current Transformers 20 5.3.4 Protection Current Transformers 20 5.3.5 Measurement Current Transformers 20 5.3.6 Current Transformer Secondary Wiring 20

5.4 Voltage Transformers................................................................................. 21 5.4.1 General Requirements 21 5.4.2 Voltage Transformer Secondary Wiring 22 5.4.3 Voltage Transformer Alarms 22 5.4.4 Voltage Transformer Supply to Protection Relays 22

5.5 Auxiliary Supply (DC) ................................................................................. 22 5.5.1 General Requirements 22 5.5.2 Requirement for Two battery Systems 23

5.6 Protection Relays ....................................................................................... 24



5.7 Close Inhibit ................................................................................................ 24 5.8 Protection Alarms....................................................................................... 24 5.9 Inter-Trip Arrangements............................................................................. 25

5.9.1 Preferred Technology 25 5.9.2 Fibre Optic Pilots 25 5.9.3 Copper Pilots 25

5.10 Integrated Support System........................................................................ 25

6 Specific Equipment Applications ................................................... 26

6.1 33kV & 66kV Feeders.................................................................................. 26 6.1.1 Standard Protection Schemes 26 6.1.2 Primary Protection 26 6.1.3 Backup protection 26 6.1.4 Circuit Breaker Fail Scheme 27 6.1.5 Location of Current Transformers 27 6.1.6 Metering Requirements 27

6.2 11kV feeders................................................................................................ 28 6.2.1 Standard Protection Schemes 28 6.2.2 Primary Protection 28 6.2.3 Backup protection 28 6.2.4 Circuit Breaker Fail Scheme 29 6.2.5 Location of Current Transformers 29 6.2.6 Metering Requirements 29

6.3 High Voltage Busbars & Bus-Tie Cables.................................................. 29 6.3.1 Primary Protection for Busbars 29 6.3.2 Primary Protection for Bus-tie Cables 30 6.3.3 Backup Protection 30 6.3.4 Location of Current Transformers 30

6.4 Rectifier Transformer and Power Cubicle ................................................ 31 6.4.1 Primary Protection 31 6.4.2 Backup Protection 31 6.4.3 Circuit Breaker Fail Scheme 31 6.4.4 Protection Interface Requirements 32

6.5 System Transformers................................................................................. 32 6.5.1 Standard Protection Schemes 32 6.5.2 Primary Protection 32 6.5.3 Backup Protection 32 6.5.4 Circuit Breaker Fail Scheme 32 6.5.5 Neutral Leakage 32



6.5.6 Buchholz Relay 33 6.5.7 Location of Current Transformers 33

6.6 11kV/415V Transformers............................................................................ 33 6.6.1 Transformers Supplied from Ring Main Units 33 6.6.2 Transformers Supplied from SCADA Controlled ACCB’s 33 6.6.3 Standard Protection Schemes 33 6.6.4 Primary Protection 34 6.6.5 Backup Protection 34 6.6.6 Circuit Breaker Fail Scheme 34

6.7 DOCUMENTATION REQUIREMENTS........................................................ 34 6.7.1 Concept Design Documentation 34 6.7.2 Detail Design Documentation 35 6.7.3 Commissioning Documentation 35

Appendix A Protection Relays ............................................................................ 37

Appendix A.1 Approved Protection Relays...................................................................... 37 Appendix A.2 Location of Protection Relays ................................................................... 38

Appendix B ACCB Trip Coils - Standard Equipment Connection .................... 39

Appendix C Two Battery Systems (125V DC) - Standard Protection Equipment Connection....................................................................................... 41

Appendix D Interfacing With Existing Pilot Wire Schemes............................... 42

Appendix E Current Transformers (33kV & 66kV) ............................................. 43

Appendix E.1 Rectifier Instantaneous Overcurrent & Earth Fault ................................. 44 Appendix E.2 Overcurrent and Earth Fault ...................................................................... 45 Appendix E.3 Pilot Wire Schemes .................................................................................... 46 Appendix E.4 Bus-Zone Schemes & Transformer Differential ....................................... 47

Appendix F Current Transformers for 11kV Switchgear................................... 48

Appendix G Protection Relay Identification ....................................................... 49

Appendix H Standard Test Block Wiring & Input/Output Relay Configuration50

Appendix I Voltage and Current Transducers .................................................. 67

Appendix J Pilot Wire Schemes ......................................................................... 68

Appendix K Auto Re-close on High Voltage Feeders........................................ 69

Appendix L Protection SCADA Alarms .............................................................. 70

Appendix M Implementation Of SCADA Alarms & Control ............................... 74



Appendix N Typical ACCB Auxiliary Supply Arrangement............................... 75

Appendix O Protection Relay Labelling Guidelines .......................................... 77

Appendix P Standard Current Transformer Configurations............................. 81

Appendix Q Protection Non-Compliances Particular to the ECRL Project...... 85

Appendix Q.1 11kV Protection........................................................................................... 85 Appendix Q.2 33kV Protection........................................................................................... 85



1 Scope and Application

This document covers the Protection System requirements for the RailCorp High Voltage AC Network for 33kV, 66kV and 132kV system voltages. The scope of this publication does not currently include specific protection scheme requirements for the high voltage AC network at 2kV system voltage. This will be incorporated in a future revision of this specification.

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

Standard Title

IEEE C.37.2 - 1996 Standard electrical power system device function numbers and contact designations.

2.2 Australian Standards

Standard Title

AS1102-1996 Graphical symbols for diagrams. Switchgear, control gear and protective devices.

AS 1675 - 1986 Current Transformers – Measurement and Protection

AS 2067 - 1984 Switchgear assemblies and ancillary equipment for alternating voltages above 1 kV

AS 1243 - 1982 Voltage Transformers for Measurement and Protection

2.3 RailCorp Documents

Document Title

EP 00 00 00 01 TI RAC Electrical system General Description

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



Document Title

TS 34 10 03 01 SP Design & Installation – Tunnel Fire safety – New Passenger Railway Tunnels

ED0001 P –ED0021 P inclusive

Engineering Design Management Procedures

2.4 Industry Publications

Network Protection & Automation Guide (AREVA) (previously titled: Protective Relays Application Guide)

Alstom/Areva Protection Relay Application Guides



3 Definitions and Abbreviations

Abbreviation Definition

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

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.

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

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

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, pole top and other distribution



substations that use HV fuses for protection are not classed as system substations.

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 RailCorp’s 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 thermal limit current of the CT’s 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”.

4.2 Protection 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 Grading

• 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 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 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 a separate auxiliary supply.

• Where two DC auxiliary supplies are required (see clause 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 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.



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 CT’s as long as the following applies:

• It is not economically feasible to install additional CT’s (eg. Circuit breaker would have to be replaced; additional post type CT’s would be required.)

• The protection schemes are not the primary and backup protection for the same equipment.

• A failure of the CT’s 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 ACCB’s 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 CT’s shall comply with 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 CT’s shall be earthed at one point. This single point earth is to be within the applicable LV compartment.

CT’s 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 1675. 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.

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

CT’s shall safely withstand the mechanical and thermal stresses set up by a short circuit equal to the full short circuit rating of the switchgear. CT’s shall have a minimum thermal limit current at least 1.5 times rated current unless modified by the RFT for the specific location.

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

See 6.2.5 for CT location requirements for 11kV Feeders.

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

See 6.5.7 for CT location requirements for System Transformers.

5.3.2 Additional Requirements for CT’s with a Rated Secondary Current of 1 Amp.

If it is proposed to use CT’s with a rated secondary current of 1A, then the following issues shall be complied with.

• Provision of a detailed design solution for the secondary wiring under system fault conditions. This design solution must address the voltage withstand ratings of all connected equipment as the secondary voltages developed are five times larger than if the CT’s have the preferred value of 5A.

• A complete integrated system support analysis of using the non-standard protection equipment must be economically justified. See 5.10 Integrated Support System for details.



5.3.3 Multiple Ratio Current Transformers

Where multiple ratio CT’s 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.

5.3.4 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 composite error shall apply:

• Differential schemes – 2.5%

• Overcurrent & earth fault – 10%

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.

5.3.5 Measurement Current Transformers

Measurement CT’s shall be of a class entirely suitable for the application as specified in AS 1675.

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

• 0.5M for general tariff metering such as supplies to shops, workshops etc.

• 2M for general measurement such as transducers and ammeters.

The measurement current transformers shall have the same ratio and thermal current limit as the associated protection CT’s on the circuit.

5.3.6 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 Areva 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

The wiring shall be a minimum size of 2.5mm2 and have an insulation rating of 0.6/1 kV. Where 2.5mm2 wiring is used it shall have a stranding of 50/0.25mm. All wiring connections to CT’s and to protection relays shall be made using double grip ring type pre-insulated crimp lugs.

Wiring identification shall be in accordance with AS2067. Refer to EP 00 00 00 15 SP Common Requirements for Electrical Power Equipment, for details of cable identification requirements.

5.4 Voltage Transformers


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 1243. They shall have a rated primary voltage as specified by the switchgear and have two secondary windings with a voltage factor of 1.9 for 30 seconds as follows:

PERFORMANCE CATEGORY

RATED VOLTAGE

ACCURACY CLASS

RATED BURDEN

A 110 V 5 P 8 mS

B (residual) 110/√3 V 3 R 8 mS

TABLE 2: Voltage Transformer Specifications

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.

High voltage fuse protection of VT’s 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.

5.5 Auxiliary Supply (DC)


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



All ACCB’s 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.

• 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)

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.

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 Substation 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. See 5.3.2 Additional Requirements for CT’s with a Rated Secondary Current of 1 Amp.

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

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 ACCB’s that were tripped by the MTM. This is to prevent the ACCB’s 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 either end of the scheme.

5.10 Integrated Support System

An Integrated Support System exists for protection equipment. This current system is based on 5 Amp CT’s 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 CT’s. 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

Primary Protection

Pilot wire Directional over-current and earth fault (looking towards supply point) and Pilot wire or Distance protection (zone 1, last 20% Zone 2) at the supply end

Backup Protection

over-current and earth fault (may be directional if required by system configuration to achieve discrimination) and circuit breaker fail

In accordance with the other Network Operator’s policy

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.



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 their ACCB’s tripped. All ACCB’s on the same busbar section as the failed ACCB shall be tripped via a multi-trip relay.

Where the operation of a breaker fail scheme shall cause a Supply Point feeder to be not available, the associated protection relay(s) shall attempt to trip the ACCB via all available trip coils. The trip coils shall be connected to separate output contact/relays of the protection relay.

6.1.5 Location of Current Transformers

It is preferred that the CT’s 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.

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.



6.2 11kV feeders


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.


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.


The failure of a circuit breaker to open in response to a protection trip command shall be detected and all ACCB’s 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.

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.


It is preferred that the CT’s 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.

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 CT’s 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.

Separate schemes shall be provided for each section of the busbar. All ACCB’s 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.


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 CT’s, 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


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 (when there is a 400V arc) 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.

See EP 03 02 00 01 SP – Controls and Protection for Rectification Equipment, for further detailed information on these requirements.


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.


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



6.4.4 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


All 33kV and 66kV transformers 750MVA 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.


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.


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 high or low voltage side of the transformer as backup protection to the outgoing feeder overcurrent protection.


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.

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.


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.

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 Merlin Gerin VIP300LL protection relay. An MMLG01 test block shall be fitted adjacent to the relay.

Transformers less then 200kVA shall be protected by fuses. 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.

6.6.2 Transformers Supplied from SCADA Controlled ACCB’s


All 11kV transformers 750kVA 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 < 750kVA 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.


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.


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.


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 three distinct stages for the submission of documentation related to the protection design and implementation for RailCorp to review.

1) The first stage is the concept design documentation.

2) The second stage is the submission of the detailed design documentation.

3) The third stage is the submission of all testing, commissioning and as-built documentation.

6.7.1 Concept Design Documentation



The following documentation is to be submitted to RailCorp prior to the procurement of any equipment that is required to meet 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 Detail Design 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 Commissioning 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)



Appendix A Protection Relays

Appendix A.1 Approved Protection Relays

The following tables detail the requirements for protection relays when new switchboards are installed in the RailCorp electrical Network.

The tables detail the protection relays which are currently preferred for use in the RailCorp electrical network and when installing a new switchboard in an existing system whether the existing pilot wire relays are required to be replaced.

SCHEME EQUIPMENT RELAY TYPE

Supply point feeder MHOB04, MiCOM P521/P540, SIEMENS 7SD610 (mandatory if fibre optic available) Pilot Wire

RailCorp feeder MBCI02* or MiCOM P521/P541 (mandatory if fibre optic available)

Feeder KCEG142, MiCOM P127

Rectifier - primary MCAG33 or MiCOM P124

Rectifier - backup KCEG142 or MiCOM P127

Current check MCAG39 or MiCOM P122

System Transformer MiCOM P127 OC, EF, DOC, DEF

11kV Distribution Transformer (refer Section 6.6)

VIP35

Busbar MCAG34 Bus-zone Bus-tie cable MCAG34, P127 (when

duplicate protection required)

Transformer differential

SystemTransformer (2 winding)

KBCH120, MiCOM P632

Neutral leakage Transformer KCEG142 or MiCOM P127

MTA MVAJ11 (with flag)



SCHEME EQUIPMENT RELAY TYPE

MTM MVAJ13 (hand reset with flag)

Intertrip GCM05 (15kV isolation)

TCS RMS 1TM10

48V DC supply RMS 1X10CAA Bus Supply

125V DC supply RMS 1X10EAA

TABLE A1: Protection Relays

• The MBCI02 pilot wire relay is a specific model for use on the RailCorp system. The relay has been modified to produce a lower voltage suitable for the insulation level of communication pilots and is Austel approved.

Appendix A.2 Location of Protection Relays

The physical location of protection relays will depend on the type of switchgear installed. In general the protection relays and associated test blocks for specific equipment shall be located together on the same panel.

This is usually on the low voltage compartment of the switchgear panels themselves (indoor switchgear) or on dedicated protection panels (for outdoor ACCB’s or indoor switchgear that does not have the physical space for installing the relays).

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

• Transformer protection - 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.



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.

EQUIPMENT PROTECTION SCHEME TRIP COIL NUMBER

NOTES

Pilot wire 1

Overcurrent & Earth Fault 2

Feeder Protection

Inter-trip 1

Busbar protection – trips via MTM

2 1 Bus-zone & Bus-Tie

Cable Bus-tie protection – trips via MTM

1 4

Differential – trips via MTM or MTA

1

Overcurrent – trips via MTA

1,2 2

System Transformers

Neutral Leakage – trips via MTA

2

Differential – trips via MTM or MTA

1 11kV/415V Transformers

Overcurrent – trips via MTA

1,2 2, 5

Instantaneous Overcurrent 1 Rectifier Transformers (primary prot’n) Earth Fault 1 via MTM

3

Instantaneous Overcurrent 2 Rectifier Transformers (backup prot’n) Earth Fault 2 & 1 via MTM

3

Rectifier Transformer

MTM 1

TABLE B1: Trip Coils

Notes:



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

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

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

4) When there is duplicate protection on the bus-tie cable the duplicate scheme shall trip the ACCB’s via trip coil 2 (via an MTM).

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



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 PROTECTION ONLY

PRIMARY & BACKUP PROTECTION LOCATED IN SAME SUBSTATION

ONE TRIP COIL

• Protection relay supply from one battery

• Trip coil supply from same battery as relay supply

• Primary protection relay supply from battery 1

• Backup protection relay supply from battery 2

• Trip coil supply from battery 1

TWO BATTERY SYSTEMS

TWO TRIP COILS

• Protection relay supply from one battery

• Trip coil 1 supply from battery 1


• Primary protection relay supply from battery 1

• Backup protection relay supply from battery 2



TABLE C1: Two Battery Systems – Connection of Equipment

Notes: 1) When there is only one battery system, the two trip coils must be supplied from

separate submains originating from the 125V DC distribution board. 2) 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.



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.

SCHEME EXISTING

EQUIPMENT

SCHEME TO BE REPLACED

NOTES

Pilot wire HO2 YES

HO4 NO 2

HMB4 NO 1,2

MHOB04 NO 1

MBCI02 NO 1

MiCOM P521/P541 NO

TABLE D1: Interfacing With Existing Pilot Wire Schemes

Notes: 1) 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.

2) If system spares are to be used to create/interface with an H04 or HMB4 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.



Appendix E Current Transformers (33kV & 66kV)

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

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.



Appendix E.1 Rectifier Instantaneous Overcurrent & Earth Fault

EQUIPMENT VOLTAGE/SIZE

CT RATIO RELAY TYPE CT DESIGNATION

MCAG33 10 P100F20 (specified on 200 tap) Rectifier Tx –

33kV 5.3, 4.28 & 2.5MVA

300/200/5 MiCOM P127 10 P50F20 (specified

on 200 tap)

MCAG33 10 P100F20 (specified on 100 tap) Rectifier Tx –

66kV 5.3, 4.28, 2.5MVA

150/100/5 MiCOM P127 10 P50F20 (specified

on 100 tap)

TABLE E1: Rectifier Protection Relays & CT’s



Appendix E.2 Overcurrent and Earth Fault

CT’s 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.

EQUIPMENT VOLTAGE/SIZE

SCHEME CT RATIO

RELAY TYPE

CT DESIGNATION

KCEG142 10P150 66kV Feeder

OC & EF 250/5

MiCOM P127 10P150

KCEG142 10P300 (specified on 300 tap)

33kV Feeder

OC & EF 500/400/300/5

MiCOM P127 10P300 (specified on 300 tap)

33/11KV Tx (5MVA )

33KV OC & EF 150/5 MiCOM P127 10P50F20

TABLE E2: Overcurrent and Earth Fault Protection Relays & CT’s



Appendix E.3 Pilot Wire Schemes

CT’s 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

250/5 MBCI02 or MiCOM P521/P541

0.3PL115R0.3

66kV Feeder

250/1 MBCI02 or MiCOM P521/P541

0.05PL50R0.8

500/400/300/5 MBCI02 or MiCOM P521/P541

0.3 PL200R0.3 (specified on 300 tap)

33kV Feeder

500/400/300/1 MBCI02 or MiCOM P521/P541

0.05 PL80R0.8 (specified on 300 tap)

TABLE E3: Pilot Wire Protection Relays & CT’s



Appendix E.4 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.

CT’s 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 (differential)

KBCH120 (two winding), MiCOM P632

33kV - 150/5 2.5P50F20

TABLE E4: Bus-Zone & Transformer Differential Protection Relays & CT’s

Notes: 1) The P632 relay should be ordered with an extra I/O module. This is required to

allow for the transformer and tapchanger alarms.



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 approval.

EQUIPMENT SCHEME CT RATIO RELAY TYPE

CT DESIGNATION

Notes

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

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

Differential 450/0.577 MiCOM P632 0.02PL100R3.0 1

OC & EF 450/1 MiCOM P127 10P50F20 33/11kV Tx

(6.25 MVA )

Neutral leakage 150/1 MiCOM

P127 10P50F20

11KV/415V Tx (1MVA ) Differential 100/1 MiCOM

P632 0.15L50R0.3 1

Busbar Buszone 600/1 MCAG34 0.03PL120R2.0 2

Bus-tie Cables Buszone 600/1 MCAG34 0.03PL120R2.0 2

Notes:

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

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



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

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 F1: Protection Relay Identification



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 electronic 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 Incoming Supplies MMLG01 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___║___13_____ + 125V dc Aux Supply MBCI&MCRI Aux ______16___x___15_____ - 125V dc Aux Supply

______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 RELAY 2-2 SPARE



MBOH04 RELAY

Relay Incoming Supplies MMLG01 MB0H04 contact (1) ______2____x____1_____ Trip +ve MB0H04 contact (3) ______4____x____3_____ Pilot Wire Trip

______6____x____5_____ Spare ______8____x____7_____ Spare

Pilot 1 MB0H04 ______10___x____9_____ Pilot 1 Pilot 2 MBOH04 ______12___x___11_____ Pilot 2 ______14___║___13_____ Spare ______16___x___15_____ Spare ______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



P521 RELAY Relay Incoming Supplies MMLG01 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___║___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 PILOT WIRE TRIP RELAY 2 TCS ALARM RELAY 3 PILOT WIRE TRIP ALARM RELAY 4 COMMS FAIL ALARM RELAY 5 SPARE RELAY 6 BREAKER FAIL ALARM RELAY 7 SPARE RELAY 8 BREAKER FAIL TRIP INPUT RELAYS: L 1 INTERTRIP INITIATE L 2 TCS INPUT L 3 SPARE L 4 SPARE L 5 SPARE



SIEMENS 7SD610 RELAY

Relay Incoming Supplies MMLG01 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___║___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 Fail Trip 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 COMMS FAIL ALARM BO3 BREAKER FAIL TRIP BO4 PILOT WIRE TRIP BO5 INTERTRIP RECEIVE Note: Output relays BO1, BO2 & BO3 are not voltage free contacts. The +125V DC for the breaker fail trip is also connected to B01 & B02 contacts by internal relay wiring.



RECTIFIER OC & EF PROTECTION

P127 RELAY

Relay Incoming Supplies MMLG01 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___║___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 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



RECTIFIER OC & EF PROTECTION

MCAG33 RELAY

Relay Incoming Supplies MMLG01 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___║___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.



33/11kV TRANSFORMER OC & EF PROTECTION

P127 RELAY

Relay Incoming Supplies MMLG01 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___║___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.



11kV DISTRIBUTION TRANSFORMER OC & EF PROTECTION

VIP35 RELAY

Relay Incoming Supplies MMLG01 TERMINAL 2 ______2____x____1_____ Trip -ve TERMINAL 3 ______4____x____3_____ Trip +ve ______6____x____5_____ Spare ______8____x____7_____ Spare TERMINAL 12 ______10___x____9_____ Io TERMINAL 13 ______12___x___11_____ Io ______14___║___13_____ Spare ______16___x___15_____ Spare TERMINAL 9 ______18___x___17_____ Ia TERMINAL 10 ______20___x___19_____ Ia TERMINAL 7 ______22___x___21_____ Ib TERMINAL 8 ______24___x___23_____ Ib TERMINAL 5 ______26___x___25_____ Ic TERMINAL 6 ______28___x___27_____ Ic



11kV DISTRIBUTION TRANSFORMER OC & EF PROTECTION

VIP300LL RELAY

Relay (x1 range 4-50A) Incoming Supplies MMLG01 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___║___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

VIP300LL RELAY

Relay (x4 range 50-200A) Incoming Supplies MMLG01 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___║___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_____ Ic



FEEDER DOC & DEF PROTECTION

P127 RELAY

Relay Incoming Supplies MMLG01 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___║___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



FEEDER DOC & DEF PROTECTION

KCEG142 RELAY

Relay Incoming Supplies MMLG01 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___║___13_____ + 125V dc Aux KCEG142 Aux ______16___x___15_____ - 125V dc Aux KCEG142 ACCB fail trip contact ______18___x___17_____ ACCB/fail trip +ve KCEG142 ACCB fail trip contact ______20___x___19_____ ACCB/fail multitrip 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



TRANSFORMER DIFFERENTIAL PROTECTION

P632/MBCH RELAY

Relay Incoming Supplies MMLG01 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.T’s) ______8____x____7_____ Ia Ib’’ (delta connected C.T’s) ______10___x____9_____ Ib Ic’’ (delta connected C.T’s) ______12___x___11_____ Ic P632/MBCH Aux ______14___║___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): K901 TX DIFFERENTIAL TRIP K701 TAP CHANGER PRESSURE

SWITCH 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



DIRECTIONAL OC/E FEEDER PROTECTION:

RELAY: MCGG52 + METI

Relay Incoming Supplies MMLG01 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___║___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



FEEDER PROTECTION, OVERCURRENT & EARTH FAULT

RELAY: MCGG52/82

Relay Incoming Supplies MMLG01 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___║___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



BUS – TIE / BUS ZONE PROTECTION

MCAG34 RELAY

Relay Incoming Supplies MMLG01 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___║___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.



RECTIFIER LOCAL BACKUP PROTECTION

MVTT14 + MCTI39 RELAYS

Relay Incoming Supplies/Contacts MMLG01 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___║___13_____ + 125V dc local bu Aux Local bu -ve ______16___x___15_____ - 125V dc local bu Aux MVTT Breaker fail trip contact ______18___x___17_____ MVTT Breaker fail trip contact ______20___x___19_____ CB/fail multitrip MCTI Ia ______22___x___21_____ Ia MCTI Ib ______24___x___23_____ Ib MCTI Ic ______26___x___25_____ Ic MCTI Io ______28___x___27_____ Io



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 0…20mA

• Mean sensing

• Self powered

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

• Areva Istat 300; Type 3CAEA513AA (for CT’s with 1A secondaries)

• Areva Istat 300; Type 3CAEA55GKA (for CT’s with 5A secondaries)

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

• Areva Istat 300; Type 3VAEA5450A, (nominal input range of 0-125V ac to measure a 110V ac voltage transformer output, usually measuring the voltage between A∅ & C∅).



Appendix J Pilot Wire Schemes



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.

The auto re-close is taken off 33kV and 66kV feeders that traverse areas considered to be a bush fire risk when fire bans are imposed. 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.



Appendix L Protection SCADA Alarms

PROTECTION SCADA ALARMS

ORIGIN OF ALARM SCADA ALARM NAME COMMENTS

ACCB SpringCharged

LowGas

LowGasLockOut

The number of alarm stages will depend on the ACCB being installed.

MotorSupply

MotorTrouble

PROTECTION RELAY

DirectionProtectionA

DirectionProtectionB

DirectionProtectionC

DirectionRelayFail

DirectionalDCSupply

PilotWireTripA

PilotWireTripB

PilotWireTripC

BrokenConductorA

BrokenConductorB

BrokenConductorC

PilotWireComms

PilotWireRelayFail

OverCurrentA

OverCurrentB





OverCurrentC

EarthLeakage

InstOverCurrentA

InstOverCurrentB

InstOverCurrentC

Inst_OC/ELtrip

OverCurrentRelayFail

BreakerFail

NeutralLeakageProtection

IntertripReceive

IntertripSend

BusZone1

BusZone2

BusZone3

BusZoneRelayFail

DifferentialProtectionA

DifferentialProtectionB

DifferentialProtectionC

DifferentialRelayFail

TripCircuitSupervision

TRANSFORMER BuchholzGas

BuchholzOil

TCBuchholzGas These alarms originate from the





TCBuchholzOil

TCFail

TCLowLimit

TCHighLimit

TCControlSupply

TCInProgress

TCIncomplete

TCRefSupplyAlarm

transformer tap changer.

TemperatureAlarm This alarm originates from the temperature indicators on the transformer. There could possibly be several stages.

VOLTAGE TRANSFORMER

PhaseFailure This alarm originates from a dedicated phase 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

BattOverVolts

BattConnected

These alarms originate from the battery charger and the exact alarms available will depend on the battery charger.



Not all the alarms in the above list will be applicable. When determining the proposed alarms the following factors must be considered:

• Type of relay

• Capacity of RTU

• Function of relay

• Value adding of the alarm information to the EOC operator and RailCorp Protection Engineer.

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.



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.

Electronic 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

• ACCB indication (both open and closed)

• ACCB DISCONNECTOR/ISOLATOR indication (all positions)*

• EARTH SWITCH indication (both open and closed)*

• Tapchanger control

• Battery Charger alarm

• 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 electronic relays having adequate RS485 communications to the RTU



Appendix N Typical ACCB Auxiliary Supply Arrangement



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 N1.

• 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: 1) Equipment being Protected/Monitored

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

2) Type of Protection

eg. DOC & DE RELAY PW RELAY A∅ DOC RELAY A∅ OC RELAY FL RELAY Tx OC RELAY Tx DIFF RELAY

3) Make of Relay in Brackets.

eg. (HMB4), (P521), (HO4) (CDD31), (P127), (CRP7), (CR LE) (P632), (KBCH), (DDT)

4) 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)

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



PROTECTION FUNCTION ABBREVIATION PILOT WIRE PW

DC REVERSE CURRENT RC

TRANSFORMER DIFFERENTIAL TxDIFF

TRANSFORMER WINDING TEMPERATURE WT

TRIP CIRCUIT SUPERVISION TCS

TRIP SUPPLY SUPERVISION TSS

TABLE N1: Protection Function Abbreviations



Appendix P Standard Current Transformer Configurations



Appendix Q 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.

Appendix Q.1 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.

Appendix Q.2 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.

Copy No.


Discipline

Electrical Engineering Standard

Category

General

Title

Electrical Power Equipment - Integrated Support Requirements Reference Number


2.0

Date of Issue

JUNE 2007

Status

Approved

Electrical Engineering Standard: General Electrical Power Equipment - Integrated Support Requirements EP 00 00 00 12 SP

Version: 2.0 © Rail Corporation Page 2 of 37 Issue Date: JUNE 2007

Prepared by

Neal Hook, Principal Engineer, Power Systems Engineering Standards & Services Division

Reviewed by


Approved by

David Stuart-Smith, Chief Engineer, Electrical Systems Engineering Standards & Services Division

Revision Summary

Authorised Version Revision

Date Details Name/Position Signature

2.0 21/06/2007 First Issue

NEAL HOOK Principal Engineer, Power Systems Engineering Standards & Services

See Revision History on page 11 for a full listing of the document changes.



DISCLAIMER

Rail Corporation of New South Wales has used its best endeavours to ensure that the content, layout and text of this document is accurate, complete and suitable for it’s stated purpose. It makes no warranties, express or implied, that compliance with the contents of this document shall be sufficient to ensure safe systems of work or operation. RailCorp will not be liable to pay compensation in respect of the content or subsequent use of this document for any other purpose than its stated purpose or for any purpose other than that for which it was prepared except where it can be shown to have acted in bad faith or there has been wilful default.

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About This Standard

This document details the integrated support requirements common to most major electrical equipment in the RailCorp high voltage and traction networks. It is designed to be used in conjunction with RailCorp technical standards for individual electrical equipment and contains information to facilitate the support of the RailCorp asset management systems including maintenance management, configuration management, quality management, risk management and financial processes.

To achieve best practice RailCorp is continually developing its asset support requirements related to its business objectives. This document will aid in the provision of information required to determine the full life cycle cost of electrical equipment through their acquisition, operational and disposal phases.

The release of this document may affect the operation or maintenance of existing electrical equipment in the RailCorp high voltage or traction network. Where integrated support requirement work is undertaken on existing equipment it shall comply with this document.



Table of Contents

1 Scope and Application............................................................................. 7

2 References................................................................................................ 8

2.1 Code of Practice ................................................................................................................8 2.2 Australian Standards.........................................................................................................8 2.3 Ex-RIC Standards ..............................................................................................................8 2.4 RailCorp Documents .........................................................................................................8 2.5 RailCorp Templates ...........................................................................................................9

3 Definitions and Abbreviations .............................................................. 10

4 Integrated Support Requirements ........................................................ 11

4.1 Integrated Support Objectives .......................................................................................11 4.2 Maintenance Requirements............................................................................................11

4.2.1 Scheduled Maintenance 11 4.2.2 Maintenance Requirements Analysis (MRA) 12 4.2.3 Failure Modes, Effects and Criticality Analysis (FMECA) 12 4.2.4 Technical Maintenance Plan (TMP) 15

4.3 Spares Support ................................................................................................................17 4.3.1 Spares Assessment Methodology 17 4.3.2 Recommended Spares List 17 4.3.3 Packaging, Storage and Handling 18

4.4 Operation and Maintenance Manual ..............................................................................18 4.4.1 General 18 4.4.2 Submission of Documentation 23 4.4.3 Scope of Manual 25 4.4.4 Validation of Content 29

4.5 Training.............................................................................................................................29 4.5.1 Training Requirements 29 4.5.2 Operator Training 30 4.5.3 Maintenance Training 30

4.6 Facilities, Equipment and Special Tools.......................................................................31

5 Revision History..................................................................................... 32

5.1 Version 1.1........................................................................................................................32 5.2 Version 2.0........................................................................................................................32

Appendix A Technical Schedule................................................................................ 33

Appendix B Request for Tender (RFT) Checklist ..................................................... 35



Appendix B.1 General .............................................................................................................................35




This document details the integrated support requirements common to most major electrical equipment in the RailCorp high voltage and traction networks. It is designed to be used in conjunction with RailCorp technical standards for individual electrical equipment and contains information to facilitate the support of the RailCorp asset management systems including maintenance management, configuration management, quality management, risk management and financial processes.

To achieve best practice RailCorp is continually developing its asset support requirements related to its business objectives. This document will aid in the provision of information required to determine the full life cycle cost of electrical equipment through its acquisition, operational and disposal phases.

The requirements of this document apply when a new piece of major electrical equipment is installed in the RailCorp high voltage or traction networks in conjunction with the relevant RailCorp standard for the equipment.

The release of this document may affect the operation or maintenance of existing electrical equipment in the RailCorp high voltage or traction network. Where integrated support requirement work is undertaken on existing equipment it shall comply with this document.



2 References

2.1 Code of Practice

The following documents are either referenced in this standard or can provide further information.


The following Australian Standards are either referenced in this document or can provide further information.

Standard Title

AS 1000 The International System (SI) units and their application

AS 1100 Parts 101 & 201 Technical Drawing

AS 1102 Graphical symbols for electrotechnical documentation

AS 1470 Health and Safety at work – Principles and Practices

AS 9001 Quality Systems – Model for Quality assurance in design/development, production, installation & servicing

2.3 Ex-RIC Standards

Standard Title

AM 9995 PM RIC Maintenance Requirements Analysis Manual

EP 00 00 00 02 SP Electrical Technical Maintenance Coding System


The following RailCorp documents are either referenced in this document or can provide further information.

Document Title



2.5 RailCorp Templates

The following drawings form part of this specification.

Use Filename

FMECA Blank FMECA sheet.xls

Service schedule(s) Blank service schedule sheet.xls

TMP Blank TMP sheet.xls



3 Definitions and Abbreviations

For the purpose of this specification the definitions specified in the referenced Australian Standards apply.

Item Description

Rotable item A major item of equipment/item/component that may be removed from its operating position for scheduled maintenance and subsequently reinstalled or replaced with a serviceable equivalent.

Consumable item A non repairable component which is damaged or wears due to use and is replaced with new component when necessary or where predetermined wear limits are reached, ( items such as contacts, lubricants, etc).

Repairable item An equipment component which may be removed from its operating position for maintenance, restored to a predetermined serviceable condition and reinstalled for a further use, such as switchgear bushings, high speed circuit breaker.

Insurance spare An equipment component purchased and stored as replacement component for use in repairing the systems to serviceable condition subsequent to the occurrence of a major incident that causes secondary damage, such as damage to OHW, train derailment and the like.

Insurance spares are normally components that are susceptible to sustaining damage beyond economical repair if involved in an incident and/or, have excessive lead times for replacement, and are required to restore a system to service.

Maintenance requirements analysis (MRA)

The process of determining the range of tasks in the maintenance schedules that will preserve the inherent levels of reliability of the design and which provide an effective and efficient means of keeping the equipment in the condition required.



4 Integrated Support Requirements

4.1 Integrated Support Objectives

The information required to operate and maintain the equipment throughout the operational life, in a cost effective manner and to a level that is consistent with the planned operational performance and usage of the systems shall be developed and provided.

This includes:

• Maintenance Requirements

• Spares Support

• Operations and Maintenance Manuals

• Training, and

• Support Equipment and Tooling

4.2 Maintenance Requirements

4.2.1 Scheduled Maintenance

The planned maintenance requirements for the equipment shall be developed and provided. Planned maintenance requirements shall as a minimum include the following, to the extent applicable to the design:

• Pre-operating procedures.

• Preventive maintenance, including service/lubrication tasks, condition monitoring requirements, scheduled restore/discard tasks, failure finding testing and any other tasks considered appropriate for all installed systems and equipment.

• Recommended overhaul requirements, including the recommended overhaul interval and location (onsite/depot/service centre).

• Details of any items subject to finite replacement or inspection lives, including structural inspections where applicable.

Maintenance checklists and procedures necessary to carry out the proposed tasks shall be defined.

Maintenance checklists and procedures shall include information on consumable items used as part of the task and reference to any special tools,



facilities or equipment needed to perform the task as well as any special skills and/or training necessary for the task.

The recommended maintenance requirements established as a result of this activity shall be documented in the form of a Technical Maintenance Plan – as defined in 4.2.4.

4.2.2 Maintenance Requirements Analysis (MRA)

The MRA process shall be undertaken in accordance with the RailCorp Maintenance Requirements Analysis Manual AM 9995 PM, which is based upon a Failure Modes, Effects and Criticality Analysis (FMECA) and Reliability Centred Maintenance (RCM) methodology. (see below)

The results of the MRA shall be documented and supplied. The Hazards and Occupational Health and Safety (OH&S) implications resulting from the MRA shall also be analysed and documented prior to completion of the respective sets of Service Schedules.

The analysis and documentation shall be undertaken using either the OEM’s in-house software tools, or the templates provided. Where in-house tools are used, hard and electronic copy of the analysis shall be provided in an agreed format to allow transfer of the information into the maintainer's systems.

4.2.3 Failure Modes, Effects and Criticality Analysis (FMECA)

A Failure Modes, Effects and Criticality Analysis (FMECA) shall be completed, documented and supplied as part of the MRA. The FMECA serves to identify potential failure modes that must be considered as part of the reliability estimation process for a specific item and to provide information on those that should receive highest priority for reliability improvement. The FMECA also provides the basis for development of programmed maintenance requirements and for identifying failure modes and effects for consideration as part of the Safety program.

The FMECA will be conducted down to the Lowest Replaceable Unit level.

The FMECA process shall be completed and documented to either:

• RailCorp’s requirements as specified in the Maintenance Requirements Analysis Manual AM9995PM, or

• the OEM’s standard, provided that the approach meets the basic objectives set out within the potential Failure Mode and Effect Analysis Handbook, which forms part of the set of documentation for the QS 9000 supplement to QS 9000 Quality Systems. The FMECA shall be documented using the OEM’s FMECA software tool.

The purpose of the FMECA is to review and analyse the equipment’s design to establish:



• Potential or demonstrated failure modes for each significant item within the design. This will be carried out at the replaceable subassembly level.

• The likelihood of failure for each identified failure mode, where possible expressed in terms of failure per million operating hours.

• The effect of failure in terms of the impact on safety, operating performance, environmental impact and economic consequences, including damage to other equipment.

• The criticality of failure in terms of operation of the system, that is, whether trains can continue to operate without delay or whether the rail systems/subsystem can continue to operate after the failure has occurred.

4.2.3.1 FMECA Worksheet documentation

The following table provides definition of the information to be included in the FMECA.

Heading Requirement

Item/Assemby, Part No and Drawing No.

Identify the asset, manufacturer's part identification, and drawing details

Analyst Identify the analyst(s) who prepared the FMECA

Functional description.

Provide an overview description of the asset's function

MTBF (hrs) Enter the asset/item's Mean Time Between Failure in hours

Function

Principal functions - which represent the business reason for an assets existence. Enter the item name and as concisely as possible the function(s) of the item to meet the design intent. Functions may also be identified in the form of a desired standard of performance with functional failure deemed to have occurred when this level of performance is not available. Include information regarding the environment in which the system operates. (eg, define temperature, voltage etc). Ancillary function - which provide additional useful functions either as enhanced capability, additional capability or opportunistic. Protective function - such as alarms and automatic shutdowns

Part The component part within the Item/Assembly which



Heading Requirement fails

Failure mode Failure modes are the effects by which failures are observed. It includes the manner by which the failure is observed & is generally described by the way in which the failure occurs and its impact, if any, on the equipment operation. Ie broken, seized, excessive vibration.

Cause of Failure Need to state the engineering mechanism of failure that leads to the particular functional or conditional failure. Failure causes are derived from the design. They are associated with the detailed design approach taken, the materials used, the operating environment including such information as physical loads and corrosive materials. Human factor information is also required, to support the allocation of warning notices in manuals or service schedules.

Local effects Identify that impact a particular failure mode has on the operation, function or status of an item. The description of the failure effect must be adequately detailed to allow classification into one of the four categories of consequences: Hidden/safety/environment Evident/safety/environment Evident/economic Hidden/economic

Failure Rate Identify the rate (in failures per million hours) at which this failure mode/cause combination occurs. If data is not available to establish exact rates, enter the indicative percentage (with % symbol) that this failure mode / cause combination represents out of the total failures

Tasks Identify maintenance task which addresses the failure mode/cause. Needs to be split maintenance tasks into and “on” or “off” system. The maintenance task must fall into one of the following categories: Service / lubrication task Condition monitoring task include examinations for indications of conditional failure before they lead to functional failure Scheduled restoration or rework at some hard time conducts a schedule of maintenance tasks Scheduled discard which at some time removes an item



Heading Requirement from the system Failure finding task which is only applicable to hidden functional failures where a confidence check that the system is still operational is required at some interval to reduce the probability of multiple failures

Type Identify type of Maintenance Task using the code letters on the worksheet.

Period Frequency for the maintenance Task - time, operational count, operational event(s), etc

Table 1 – FMECA worksheet

4.2.4 Technical Maintenance Plan (TMP)

The recommendations resulting from the maintenance analysis process shall be documented in the form of a Technical Maintenance Plan (TMP) for the system using the RailCorp Service Schedule and TMP Templates.

The TMP shall include details of:

• The equipment.

• All scheduled maintenance activities for the equipment.

• The intervals (periodicity) at which each maintenance schedule should be performed.

• Skills and competencies for completion of each major task in the schedule. Note that for the purposes of the TMP a “task” may comprise a number of actions performed as part of a scheduled examination.

• Recommended location at which the schedule is to be completed eg on-site, depot, workshop, central facility, etc.

• Details of special facilities or equipment necessary for completion of the schedule.

• Reference to technical data or inspection schedules required for completion of the task.

• Checklists for recording the results of the maintenance processes.

The terminology used in the service schedule tasks shall be in accordance with 4.2.4.1. Refer to section 4.3.6 of AM 99 95 PM RailCorp Maintenance Requirements Analysis Manual for further details.



4.2.4.1 Service Schedule standard terminology

The words used to define maintenance actions shall be standardised to ensure consistency of approach and to assist the transfer of information across application boundaries. Consistency of task description enables the provision of a common interpretation of instructions and task directives by all support staff.

Each task statement should have the standard structure shown at Figure 1

VERB NOUN CONDITIONAL STATEMENT

Examine attachment blocks securityfor

Figure 1 - Standard task statement structure

The verbs are the key words which define the task action and have a standardised description. The remainder of the statement will depend on the particular item and failure mode and hence use conventional English meanings. These key verbs are listed in Figure 2:

Verb Detailed requirement

Examine Carry out a visual survey of the condition of an item without dismantling (unless directed to do so by the maintenance instruction).

Lubricate Apply a specified lubricant (e.g. oil type XYZ, grease type ABC) to a specified area of equipment (often specified in a separate lubrication chart).

Check Make a comparison of a measurement of some quantity (e.g. time, pressure, temperature, resistance, dimension) to a known value (accept/reject criteria) for that measurement and if required rectify and/or replenish if necessary.

Check Operation or Operate

Ensure that an item of equipment or system functions correctly as far as possible without the use of test equipment or reference to a measurement.

Clean Remove contaminating materials (e.g. dust, dirt, moisture, excessive lubricant) from an item of equipment.

Adjust To alter as necessary to make an item compatible with system requirements.



Verb Detailed requirement

Test Determine by using appropriate test equipment that a component of equipment functions correctly.

Replenish Refill a container to a predetermined level, pressure or quantity and undertake associated access and closure tasks.

Fit Correctly attach an item to another.

Refit Fit an item that has been previously been removed.

Calibrate Make a comparison of a measurement of time, pressure, temperature, resistance, dimension or other quantity to a known standard (usually a NATA laboratory function).

Disconnect Uncouple or detach cables, pipelines or controls.

Reconnect Reverse of disconnect.

Safetyseal Securing of equipment which requires the breaking of a seal to manually operate (usually associated with emergency equipment).

Remove Correctly detach one item from another.

Secure To make firm or fast.

Figure 2 - Task verbs - standard terminology

4.3 Spares Support

4.3.1 Spares Assessment Methodology

The need for spare parts shall be assessed and the spare parts list developed using a clearly defined methodology.

The methodology shall use established failure rates and the related maintenance policies, and identify the range and quantity of spares to be made available at any time to maintain the systems and ensure they meet the availability requirements. The need for insurance spares to meet unplanned needs shall be addressed, and a separate assessment process used to identify, quantify and list these insurance spares.

The methodology to be used for the assessment of spares requirements must be included in the Maintenance Plan.

4.3.2 Recommended Spares List

A recommended spares list shall be developed and provided. The recommended spares list must define the recommended range and quantity of



rotable and repairable items, consumables and insurance spares to support the planned operational usage with the recommended maintenance policies.

The recommended spares list shall be developed and refined during the design and construction of the equipment.

The recommended spares list shall include the following information:

• item identification (name, manufacturers part or reference number and specification, as appropriate);

• recommended spares quantities;

• expected price;

• source;

• procurement lead time;

• failure rate;

• number of items installed in the equipment

• predicted usage rate and whether the item is consumable or is used in support of scheduled preventative maintenance; and

• probability of the required item being available based on the recommended spares quantity and procurement lead time.

4.3.3 Packaging, Storage and Handling

The requirements for packaging, storage and handling shall be provided for all recommended spares.

4.4 Operation and Maintenance Manual

4.4.1 General

An Operations and Maintenance Manual shall be provided for the equipment, and shall meet the requirements below. The manual shall be delivered in hard copy and in electronic format. (see below).

Manuals may be produced to meet the specification below, or supplied as standard manuals in the OEM’s proprietary format, provided that the information required in 4.4.3 below is clearly contained within the combination of manuals, and any attachment. Manuals shall only contain information about the equipment supplied. Where the OEM’s proprietary manuals contain information and references to multiple models of equipment, information relating to unsupplied equipment shall be clearly crossed or blanked out.



Hard copies of the manual shall have the following features:

Binding

• Bound; or

• Contained in white, durable, four ring hard cover binders, not greater than 50 mm thick, with the facility, equipment or plant identification permanently marked on the spine and outside cover with clear protection on the covers. Binders shall not be filled to more than 60% capacity.

Paper

• Not less than 80 gsm in weight, surface sized and suitable for offset/laser printing, in double-sided form;

• Text on A4 pages

• Illustrations on A3 size paper folded to A4 size

Typeface and layout

• Clear typeface;

• 35 mm margin for binding;

• Each section shall start on a right hand side page;

Organisation

• Divide sections with indexed plastic divider sheets ;

• Protect vulnerable and much used pages with plastic covers;

• Index the contents

• Locate illustrations and at the rear of the text. Small illustrations, to highlight matters, may be located in the text;

• Commence each document with a title sheet detailing as a minimum:

1) Name of System/Element/Item/Equipment;

2) Supply Contract Details (if applicable);

3) Name of Supplier (if applicable);

4) Address for Service Calls (if applicable), and

5) Document version # and date of issue



The electronic form of the document shall be delivered in two forms:

• Microsoft Word97 format (for custom produced manuals),

• PDF File(s), with all headings down to level 3 linked to the appropriate page/section in the pdf file(s). The PDF files shall also include pdf versions of OEM information, Works/Test certificates and other hardcopy documents to produce a pdf version of the entire manual. Clear scanned images with a resolution for legibility incorporated into pdf files are acceptable. When the individual pdf files are generated they shall not be password protected, and shall be enabled for editing to enable the pdf file size to be reduced where required for more efficient intranet access. Or

Approved equivalent appropriate industry standard software as may be appropriate at the time of delivery of this documentation

4.4.1.1 Word Processor Configuration for Custom Produced Manuals

4.4.1.1.1 Text Styles and page settings

The following settings and styles shall be used to produce the printed pages of the manual.

Page Size A4 Margins Top 2 cm Bottom 2 cm Left 2 cm Right 2 cm Header (from edge) 1.25 cm Footer (from edge) 1.25 cm Gutter 1.5 cm

Text Styles Heading 1 Arial, 14pt Bold, indent: hanging 2.06cm,

paragraph spacing 12pt before, 6pt after, outline numbered, level 1

Heading 2 Arial, 12pt Bold, indent: left 1.25cm, hanging 1.73cm, paragraph spacing 6pt before, 6pt after, outline numbered, level 2

Heading 3 Arial, 12pt, indent: left 1.25cm, hanging 1.73cm,paragraph spacing 6pt before, 3pt after, outline numbered, level 3



Heading 4 Arial, 12pt, italic, indent: left 1.25cm, hanging 1.73cm, paragraph spacing 6pt before, 3pt after, outline numbered, level 4

Normal Arial, 11pt, indent left 2.0cm, paragraph spacing 6pt before and after, line spacing (at least) 12 point.

Table text Arial, 11pt, left indent 0.1cm, right indent 0.1cm paragraph spacing 1pt before and after, line spacing (at least) 12 point.

Caption Arial, 8pt, bold, centred, paragraph spacing 3pt before and after.

Warning Normal + indent left 3.0cm, indent right 2.5cm

Header Arial, 10pt italic, Tabs:9cm centred, 15.5cm right flush

Footer Arial, 10pt italic, Tabs:9cm centred, 15.5cm right flush

4.4.1.1.2 Table of Contents

The table of contents for the manual shall commence on page iii of the document and the table shall be created from style heading levels 1 to 4 inclusive. It shall be followed by a list of Figures and a list of Tables.

4.4.1.1.3 Page Numbering

The introductory pages of the manual shall be numbered consecutively in roman numerals (i, ii, iii, iv etc).

Each section of the manual shall be consecutively numbered in Arabic numerals, and be presented as ‘page x of y’, where y is the number of pages in the section of the manual.

The introductory pages shall include the title page, Revision Control Table (see 6.1) and table of contents.

4.4.1.1.4 Numbering methodology

The sections and subsections of the manual shall be outline numbered. Sections shall be numbered sequentially from 1.0 and shall be style ‘Heading 1’

Subsections shall be numbered sequentially within the section from n.1 and shall be style ‘Heading 2’

The section and subsection titles are listed in 4.4.3.



Tables may be used to where applicable to simplify the presentation of information and data interpretation. Tables shall be numbered sequentially within each section using Arabic numerals in the order they appear in the text. Table numbering shall be of the form ‘Table n-1’ where n is the section number and it shall prefix the title of the Table. The figure text shall be style ‘caption’. The text within the tables shall be of style ‘table text’.

Figures shall be numbered sequentially within each section using Arabic numerals in the order they appear in the text. Figure numbering shall be of the form ‘Fig. n-1’ where n is the section number and it shall prefix the title of the figure. The figure text shall be style ‘caption’.

4.4.1.1.5 Page header

The header shall be formatted as style ‘header’ and shall have a 1 pt border line below the header paragraph. The content of the header lines of each section shall be:-

Line 1

Manual Title Left flush Section Name at Tab 9 cm, centred Manual Number at Tab 15.5 cm, right Flush

Line 2

Section Revision Date Left flush Section Revision Number at Tab 15.5 cm, right Flush

4.4.1.1.6 Page Footer

The footer shall be formatted as style ‘footer’ and shall have a 1 pt border line above the footer paragraph. The content of the footer lines of each section shall be:-

© Rail Infrastructure Corporation

Left Flush

‘Section n - page x of y’ at Tab 15.5 cm, right Flush

4.4.1.1.7 Warnings and Cautions

Where it is essential for the protection of the staff and / or equipment the manuals shall include the appropriate Warnings, Cautions and notes. The format of the text shall be style ‘ Warning’. The content of a warning box shall not be split over two pages. Warnings and cautions shall not contain procedural steps, nor be numbered. Where the warning or caution contains more than one critical element, those elements should be separated by the use of bullet points for each separate element.



Warning shall be used for the protection of staff, Caution used for the protection of the equipment, and Note used to draw attention special requirements.

Where a combination of warning, caution or note appear together they shall appear in the order of Warning, Caution then Note as applicable.

4.4.2 Submission of Documentation

Operation and Maintenance Manuals shall be provided and be written in clear, concise English, produced in the format outlined above, and covering the following scope and content.

4.4.2.1 Document Numbering

The number format shall be AA aabbcc ZZ, where:

• AA is the relevant discipline code from the RailCorp TMP,

• aabbcc represent the next three layers of the RailCorp Technical Maintenance Code (TMC), and

• ZZ is “MP” for a manual covering a system or subsystem, or “EQ” where the manual covers only one equipment group.

Refer to EP 00 00 00 02 SP “Electrical Technical Maintenance Coding System”.

Revision numbers for draft versions of the Manuals shall be A, B, C etc.

Revision numbers for approved versions of the Manuals shall be 1, 2, 3 etc.

The document number shall be unique and shall be registered in the RailCorp master list of document numbers prior to document development commencing.

4.4.2.2 Inclusion of Drawings and Photographs

Figures and/or pictures should be included where appropriate to complement the manual text. They shall be used to:

• Present information difficult to describe by text alone;

• Provide identification of tools, parts etc;

• Halftone figures (photographs) where used, shall be suitable for electronic scanning and photocopying without loss of detail.

4.4.2.3 Folders

Where required the contents of the manual may be spread over multiple folders. Each folder shall be called a Volume. Where volumes are utilised, a complete table of contents for the entire manual shall be included in each volume, clearly indicating which sections are located in each volume.



4.4.2.3.1 Covers and Spines

The cover page for each volume shall be inserted as the first page within each volume, and a copy inserted into the front cover of the volume.

The spine shall contain the Manual Identification Number, the volume number, and the numbers of the sections in the respective volume where the manual is split over more than one volume. The text shall be sized to suit the thickness of the folder. The spine identification box shall be positioned 5 cm from the top edge of the folder

4.4.2.3.2 Revision History

The revision history of the manual shall be included in a Revision Control Table on page ii of the Operations and Maintenance Manual. See following sample page for layout of revision control tables.

Sample Revision Control Table Page.

Revision Control Table

Revision Date of Approval

Summary of change

1 Sept 2002 Original Issue

2 Dec 2002 Section 4.3 revised

Current Subsection Revision

Subsection Current Revision

Summary of change

Title page 1 Original Issue

Revision Control

2

Table of Contents

2

1.0 1 Original Issue

2.0 2 Updated description of HV circuit breakers


4.0 – 4.2 1 Original Issue



Subsection Current Revision

Summary of change

4.3 2 Updated alarm test procedure

4.4-4.5 1 Original Issue





4.4.3 Scope of Manual

The following information shall be included (where applicable) in the general order detailed below, in separate Operation and Maintenance Manuals for separate operable systems, types of items, geographic areas and the like.

Section 1 Purpose of the Manual 1.1 Brief description of the Manual’s purpose, structure and content. 1.2 References and associated publications and standards. 1.3 Definitions.

Section 2 Equipment Description 2.1 Physical Description of equipment and major components. 2.2 Principles and theory of operation. This section should explain enough so that fault finding can be sensibly carried out. Line type illustrations are appropriate. Summary of the key Design Parameters of the various elements of the equipment that need to be known in its operation, maintenance and management. A basic working description, including features and any automatic control, operational purposes and functions of the components, systems and items. For software oriented systems, functional specifications (hardware and software), systems programs, individual program modules, including flow charts and source codes, and the like. 2.3 Detailed component description. Each major component illustrated and described. 2.4 Operating Instructions and Procedures. Comprehensive details of technical information relevant to modes of operation with



a step by step procedure arranged into sections, such as: Safety Procedures and inherent hazards to be documented including applicable material safety data sheets. This information will be used as input for Job Safety Analysis and pre work briefing. The JSA and pre work briefing to be undertaken by RailCorp; Operating ratings and limitations due to temperature, pressure and flow, or other relevant factors; Checks before, and procedures for, Equipment Startup, Operations and Shutdown; Emergency Shutdown and Abnormal Operation; Full information on alarm and trip settings; Full details on condition monitoring capability including accept/reject criteria Links to inspection, servicing and maintenance schedules as defined in the Maintenance Plan; Any other information needed by operating staff to ensure the safe and efficient operation of the equipment.

Section 3 Operational and functional checks Describe the tests required to confirm operation and whether the equipment and its components are functioning within acceptable limits. Specify accept and reject limits and tolerances.

Section 4 On system maintenance Refers to maintenance carried out on the installed site. 4.1 List of tasks; 4.2 Tools and materials; 4.3 Maintenance tasks. Comprehensive step by step instructions in preventative and corrective maintenance procedures, nominating the work to be carried out by qualified tradespersons and others Safety procedures Maintenance standards Maintenance instructions for each of the service periods. Location of maintenance action (on-system, workshop etc). Consumables and special tools required. List of recommended greases and oils, stating quantities, methods and frequency for application.

Section 5 Fault diagnosis



Describe a series of sequential actions to diagnose equipment faults. It is important that the operational requirements are included in these sequences. Troubleshooting instructions in tabular form listing “fault”, “possible cause” and “remedial action”, with testing regimes and instructions.

Section 6 Removal and Installation Describes procedure for transport, installation, commissioning or removal of the equipment or components. It shall include information on support equipment, packaging, handling, transport and storage requirements.

Section 7 Overhauling Step by step instructions and procedures for complete overhauls, indicating those procedures to be carried out by qualified tradespersons, described under at least the following subheadings: Material safety data Sheets Handling precautions Dismantling Cleaning, Inspection, Repair and Adjustment Reassembly Final Checks and Unit Running



Section 8 Spare Parts Data on spare parts supplied under the following headings:- “List of Suppliers”, stating: Manufacturer Manufacturer’s nearest representative Company address Telephone and Facsimile numbers “Illustrated Parts List”, including: A list (or lists) of parts with part numbers referenced to an illustration, preferably an exploded view of sectional drawing and a specification “Recommended Spare Parts”, including: The list of recommended spare parts with part numbers and quantities and a separate list of spare parts supplied under this Contract to the Principal’s Representative “Availability of Spare Parts”, including: A short statement quoting the worst case procurement lead time/availability to suit the quantities of parts from suppliers “Ordering Information”, including: Specific details that would be required when ordering replacement parts, such as serial number, model number, name, reference number and the like “Special Tools”, including: A list of any special tools required when for periodic maintenance or overhauls

Section 9 References Summary tabulation and details of all applicable Certificates, Warranties and Guarantees related to the asset with cross reference to the location of the originals. (Originals of all Certificates, Warranties and Guarantees must be provided as handover documentation, in a logical grouping for particular assets, labelled in such a manner as to provide traceability.) Tabulation of Consultants, Sub-Consultants, Service providers, Suppliers and other Subcontractors and utilities/service providers,



together with contact details for each significant element of the assets. Reference to all commissioning records/results and reports.

Section 10 Quality Records This section shall provide details and the respective forms (where required) of all records that are required for maintenance and breakdown actions. These shall be presented in tabular form, and sample forms produced one form per page in the manual. Each form shall be delivered in a separate file of native format (eg. MS Word or MS Excel)

Section 11 Test Certificates All works and site test/commissioning certificates for the system/ subsystem and equipment shall be included in this section.

Section 12 Hard copy of Work-as-Executed Drawings This section shall include a complete list of the drawings associated with the manual. The PDF version of the manual shall link to a PDF or TIFF copy of the each corresponding drawing.

4.4.4 Validation of Content

The operations and maintenance documentation provided must be validated prior to commissioning and used as part of the training provided by the OEM.

4.5 Training

4.5.1 Training Requirements

A training program shall be developed, provided and implemented. This shall cover each part of the equipment as specified by the RFT and address the following issues for each training course:

• specific training objectives;

• training methods for the operation and maintenance personnel;

• training documentation, aids and material necessary to support the training;

• training syllabus, course outlines, training notes, content plans, in the form of a training manual, meeting the defined training course objectives;

• cover both operations and maintenance requirements including testing and operational evaluations.



The training shall be designed for appropriately qualified personnel requiring only specialised training required on the relevant systems.

The training shall be conducted only by persons who are appropriately skilled, qualified, experienced and competent in the field involved, and who have completed formal training in instruction techniques.

All training aids and material must be up to a good commercial standard and appropriate for the training to be conducted.

Training may be conducted on a site where the equipment is installed or off-site. The required location for training will be stated in the RFT.

Where training is to be conducted off-site and access to particular equipment is required, training must be undertaken on equivalent duplicate equipment to that installed on RailCorp’s network. Off site training must be supplemented with visits to the applicable installed system on the Site. If no location for off-site training is specified in the RFT, off-site training shall be provided in Sydney.

4.5.2 Operator Training

The training program shall cover and address operations and site familiarisation training for electrical operators who will be required to operate, isolate and earth electrical equipment:

The operator training shall be designed for persons qualified under the RailCorp Electrical Safety Instructions and experienced in the operation of existing electrical High and Low voltage infrastructure that is part of the Sydney railway network.

The training shall include the:

• theory and practice of the operation of the equipment and its constituent parts and systems;

• controls and instruments;

• safety and emergency operations; and

• techniques for checking, testing and adjusting systems.

4.5.3 Maintenance Training

Specific maintenance training shall be included for personnel responsible for:

• routine examination and servicing;

• repair systems, including the temporary and permanent repair of damage caused through vandalism, collision or other unscheduled event; and



• specialist processes such as on site fault finding, removal and replacement, functional or operational testing to a level necessary to support the systems involved.

Maintenance training shall include familiarisation with the equipment, and the specific maintenance requirements for all system, subsystem and ancillary equipment arrangements.

Maintenance training shall also cover the engineering management of the systems for engineering staff.

4.6 Facilities, Equipment and Special Tools

A list of special tools, facilities and equipment necessary for the operation and maintenance of the systems shall be developed and provided.

The list shall:

• include the recommended number of special tools, facilities and equipment required for the operation and maintenance of the equipment;

• identify the items required to perform specific maintenance, repair and recovery tasks on the equipment, including scheduled preventative maintenance of the equipment, the removal, installation and testing of rotable and repairable items, and other procedures, such as temporary repairs during normal operating periods for unscheduled failures with follow-up maintenance and emergency recovery; and

include any special purpose test equipment and facilities needed in support of the maintenance tasks, including specialist hand-tools.

This list of special tools, facilities and equipment must include:

• details of, and a specification for, each item;

• purpose of the item;

• maintenance requirements for each item,

• supplier;

• the quantity required;

• price and validity period expected;

• packaging, storage and handling requirements; and

• delivery times.



5 Revision History

5.1 Version 1.1

• Added to Appendix A 4.2.1Scheduled Maintenance the requirement at tender stage to provide a preliminary list of scheduled maintenance and methodology to facilitate life cycle costing assessment.

5.2 Version 2.0

• Updated to RailCorp Standards formatting. Changed hyperlink from 3.3.3 to 3.4.2



Appendix A Technical Schedule

The Tenderer shall supply the information listed in this Technical Schedule at tender stage. This information will be used as an aid to assess the life cycle cost of each tender and to confirm that tenderers understand the importance of the integrated support requirements in the procurement process.

4.2.1 Scheduled Maintenance

Provide details of a preliminary scheduled maintenance list including methodology for this list..

4.2.2 Maintenance Requirements Analysis (MRA)

What analysis and documentation tools are to be used?

RailCorp templates or OEM’s in house software If OEM’s in house software is used please provide details of documentation and past usage.

Provide details of experience with MRA/RCM analysis and documentation.

4.2.3 Failure Modes, Effects and Criticality Analysis (FMECA)

What method of FMECA will be used?

RailCorp templates or OEM’s in house software If OEM’s in house software is used please provide details of documentation and past usage.

What is the source and extent of the data used in the FMECA – provide detail.Is the FMECA based on operational experience – provide detail.

4.3.1 Spares Assessment Methodology

What methodology for spares assessment will be used?

Please provide details of documentation and past usage.

Provide details of a preliminary spares list including methodology for this list.

4.3.3 Packaging, Storage and Handling Any special requirements for packaging, storage and handling for the equipment or recommended spares to be provided.

4.4 Operation and Maintenance Manual

What format are the manuals to be supplied?

Microsoft Word97 format or OEM proprietary format modified to meet all requirements of section 4.4.3 of this standard. If OEM’s format is used please provide



details of documentation and past usage.

4.5 Training

Please provide details of anticipated delivery method, location, qualifications (technical and training) of personnel and list of resources.



Appendix B Request for Tender (RFT) Checklist

Appendix B.1 General

Where this standard is used as a supporting document for the integrated support requirements for the procurement of a major item of electrical equipment, the following information must be considered for the particular situation, and provided to the tenderers if required. All the items listed in this document may not be required. The Request for Tender must be specific in highlighting which clauses are mandatory, which clauses are optional and which clauses can be deleted. The following issues must be considered in making these determinations for each RFT:

• Previous usage of identical or similar equipment in the RailCorp network;

• The number of items of equipment; and

• The planned geographical spread of the equipment in RailCorp network;

• The complexity of equipment;

• The cost of equipment;

• The cost of the total order.

Maintenance Requirements

The RFT must indicate that the equipment supplier must provide all of the information set out in clause 4.2 Maintenance Requirements.

The tenderer should also be made aware that if they are successful they must submit the FMECA at least 28 days prior to the delivery of the equipment;

Spares Support

The RFT must indicate that having completed the spares assessment methodology of clause 4.3 Spares Support the equipment supplier must provide the Recommended Spares List as set out in clause 4.3.2.

The tenderer shall provide a preliminary spares list, refer to Appendix A Technical Schedule both in the equipment standard for the particular item of electrical equipment and this document.

The decision for the procurement of spares is an iterative process and should be addressed as such by the RFT. Once the successful tenderer has provided the detailed spares list (which should be consistent with the original proposed spares list provided as part of the tender) and methodology, a RailCorp representative must then review the life cycle cost analysis in conjunction with the existing RailCorp spares. Note that it is a RailCorp responsibility to determine the system spares policy.



Packaging, Storage and Handling

The RFT must indicate that the equipment supplier must provide all of the requested information in clause 4.3.3

Operation and Maintenance Manual

The document number, as described in clause 4.4.2.1 Document Numbering, must be supplied to the successful tenderer.

The successful tenderer must:

• submit two unbound draft hard copies of the Operations and Maintenance Manual at least 28 days prior to the delivery of the equipment;

• ensure the draft manuals must meet all the formatting requirements of clause 4.4

• act on comments made on, and correct deficiencies in, the draft copies and supply the final bound hard copy sets and electronic sets incorporating all the changes needed by the equipment delivery date;

The number of hard copies of the manual shall be a minimum of five (5) (or 1 each location if required, 1 each field engineering office, 1 for Design) and the number electronic versions on CD shall be two (2) (or 1 each field engineering office, 1 for Design). The RFT must specify total hardcopy required.

Training

For the tenderer to determine the training requirements of clause 4.5 Training, the tenderer must be informed of the number of staff nominated for each type of training.

The RFT must indicate that the equipment supplier must provide the training program and training manual for review at least 28 days before any training takes place.

The RFT must nominate location for on-site, and off-site training to be delivered. Refer to clause 4.5.1.

Facilities, Equipment and Special Tools

The RFT must indicate that the equipment supplier must provide the list of special tools, facilities and equipment as set out in clause.4.6

A final list of special tools, facilities and equipment shall be submitted not later than 28 days prior to delivery of the first installation or in sufficient time for essential items to be available for use with training, whichever is the earlier.

The RFT must specify details of the process to procure the range of special tools, facilities and equipment required following the submission and review of the recommended list. Refer to clause 4.6.



The RFT must indicate that the tenderer must provide a preliminary list of special tools, facilities and equipment with the tender.

Quantity and Costing of Integrated Support Deliverables

The RFT shall state the quantity of each deliverable required and request a breakdown of the cost for the various items to facilitate the full life cycle cost analysis. The list of deliverables to be costed shall include:

• Provision of Operations and Maintenance manuals in accordance with clause 4.4;

• Provision of training aids and material for the Principal’s use in undertaking future training.

Provision of training in accordance with clause 4.5. The training costs are to be broken down into separate costs for Operator Training and Maintenance Training.

Copy No.


Discipline

Electrical Engineering Standard

Category

General

Title

Common Requirements for Electric Power Equipment Reference Number


2.0

Date of Issue

JUNE 2007

Status

Approved

Electrical Engineering Standard: General Common Requirements for Electric Power Equipment EP 00 00 00 15 SP


Prepared by


Reviewed by


Approved by


Revision Summary



2.0 01/06/2007 First Issue




DISCLAIMER

Rail Corporation of New South Wales has used its best endeavours to ensure that the content, layout and text of this document is accurate, complete and suitable for it’s stated purpose. It makes no warranties, express or implied, that compliance with the contents of this document shall be sufficient to ensure safe systems of work or operation. RailCorp will not be liable to pay compensation in respect of the content or subsequent use of this document for any other purpose than its stated purpose or for any purpose other than that for which it was prepared except where it can be shown to have acted in bad faith or there has been wilful default.

DOCUMENT APPROVAL







COPYRIGHT




About This Specification

This document details the common requirements for electric power and control cubicles or assemblies forming part of switchgear, rectification equipment, transformers and similar equipment deployed in the Electric Power sub-system of RailCorp. It includes requirements relating to the equipment as a whole and components used in the equipment, to both hardware and software aspects and also the data set associated with the equipment.

The requirements of this document apply to new power and control cubicles or assemblies as well as existing equipment that is modified or refurbished.

It is intended that this document be called up in other documents and these requirements only apply when this document is referred to in the primary specification for the equipment.



Table of Contents

1 Scope and Application............................................................................. 7

2 Normative References ............................................................................. 8

2.1 Code of Practice ................................................................................................................8 2.2 International Standards.....................................................................................................8 2.3 Australian Standards.........................................................................................................8 2.4 RailCorp Documents .........................................................................................................9 2.5 RailCorp Templates ...........................................................................................................9

3 Technical Requirements........................................................................ 10

3.1 Panels and Doors ............................................................................................................10 3.2 Painting.............................................................................................................................10

3.2.1 Indoor Equipment 10 3.2.2 Outdoor Equipment 10

3.3 Cable Entry.......................................................................................................................11 3.4 Access ..............................................................................................................................11 3.5 Lifting Points....................................................................................................................11 3.6 Fixing Points ....................................................................................................................11 3.7 Colour Convention for Controls and Indications .........................................................11

3.7.1 1500V and High Voltage Devices 11 3.7.2 Low Voltage Devices 12

3.8 Equipment Mounting.......................................................................................................12 3.9 Labelling ...........................................................................................................................12

3.9.1 Language 12 3.9.2 Equipment Labels 12 3.9.3 Terminal Strip Labels 13 3.9.4 Wire Identification & Numbering 13 3.9.5 Cable identification codes for schematics, cable schedule and drawings 13

3.10 Auxiliary Supply Voltage.................................................................................................14 3.10.1 Traction Substation – DC auxiliary supply 14 3.10.2 Traction Substation – AC auxiliary supply 15 3.10.3 DC auxiliary supply – other than traction substations 15 3.10.4 AC auxiliary supply – other than traction substations 15

3.11 Wiring................................................................................................................................15 3.11.1 General 15 3.11.2 Termination 16 3.11.3 Minimum Wire Size and Wire Type 16



3.11.4 Wire Colours 16 3.12 Terminal Blocks ...............................................................................................................16 3.13 Earth terminal...................................................................................................................17 3.14 Light ..................................................................................................................................17 3.15 Auxiliary Relays, Push Buttons, and Selector Switches.............................................17

3.15.1 Contacts 17 3.15.2 Relays 17 3.15.3 Suppression Diodes 17 3.15.4 Trip Circuit Supervision 17 3.15.5 Indicator Lights 18

3.16 Programmable Equipment..............................................................................................18 3.17 Current Transformers......................................................................................................18 3.18 Metering............................................................................................................................18 3.19 Selection of Components and Equipment ....................................................................19 3.20 Environmental..................................................................................................................19

4 Maintenance Concept ............................................................................ 20

5 Testing .................................................................................................... 21

5.1 Type Tests ........................................................................................................................21 5.2 Routine Tests ...................................................................................................................21

6 Data Set Associated With The Equipment ........................................... 22

6.1 Drawings...........................................................................................................................22 6.1.1 Drawings Required 22 6.1.2 Manufacturers Standard Drawings 23 6.1.3 Project Drawings 23

6.2 Test Results .....................................................................................................................25

7 Appendices............................................................................................. 26

Appendix A Schematic Diagram Identifiers.............................................................. 27

Appendix B Request for Tender Checklist ............................................................... 31

Appendix B.1 Application .......................................................................................................................31 Appendix B.2 Information to be supplied to the Tenderer ..................................................................31 Appendix B.3 Information to be provided by equipment suppliers ...................................................33

Appendix B.3.1 Label Schedule 33 Appendix B.3.2 Inspection and Test Plan 33 Appendix B.3.3 Drawings 33

Appendix C AutoCAD to Microstation Specifications ............................................. 35




This document details the common requirements for electric power and control cubicles or assemblies forming part of switchgear, rectification equipment, transformers and similar equipment deployed in the Electric Power sub-system of RailCorp’s infrastructure. It includes requirements relating to the equipment as a whole and components used in the equipment, to both hardware and software aspects and also the data set associated with the equipment.

The requirements of this document apply to new power and control cubicles or assemblies as well as existing equipment that is modified or refurbished.

The standard RailCorp relay and circuit naming conventions are included at Appendix A.

The release of this document will not affect the operation or maintenance of existing power and control cubicles or assemblies in the RailCorp network.



2 Normative References

2.1 Code of Practice

The following documents contain provisions that, through reference in this text, constitute provisions of this specification.

At the time of publication, the editions indicated were valid.


Standard Title

IEEE C.37.2 -1996 Standard electrical power system device function numbers and contact designations.



Standard Title

AS 1042 – 1973 Direct-acting Indicating Electrical Measuring Instruments and their Accessories. (Withdrawn)

AS 1102 – 1997 Graphical symbols for Electrotechnical Documentation

AS 1675 - 1986 Currrent Transformers - Measurement and Protection

AS 60044.1 – 2007 Instrument Transformers – Current Transformers.

AS 1939 Supp 1 – 1990

Degrees of protection provided by enclosures for electrical equipment (IP Code) – Wallchart 1

AS 1939 Supp 2 – 1990

Degrees of protection provided by enclosures for electrical equipment (IP Code) – Wallchart 2

AS 2067 – 1984 Switchgear assemblies and ancillary equipment for alternating voltages above 1 kV

AS 2700 – 1996 Colour Standards for General Purposes.

AS/NZS 3000 – 2000

Electrical Installations (known as the Australian/New Zealand Wiring Rules)

AS/NZS 3439.1 – 2002

Low-voltage switchgear and controlgear assemblies – Type-tested and partially type-tested assemblies.

AS/NZS 5000.1 – Electric cables – Polymeric insulated – For working



Standard Title 2005 voltages up to and including 0.6 / 1 (1.2) kV

AS/NZS 5000.2 – 2006

Electric cables – Polymeric insulated – For working voltages up to and including 450/750 V

AS/NZS 5000.3 – 2003

Electric cables – Polymeric insulated – Multicore control cables

AS 60038 – 2000 Standard voltages

AS 60529 – 2004 Degrees of protection provided by enclosures (IP Code)


The following RailCorp documents are either referenced in this document or can provide further information.

Document Title

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

ED 0022P CAD and Drafting Manual – All Design Areas

ED 0024P CAD and Drafting Manual – Electrical

2.5 RailCorp Templates

The following templates are provided for documentation:

Use Filename

Cable schedule Blank Cable schedule.xls



3 Technical Requirements

3.1 Panels and Doors

All panels, including doors, shall generally be constructed of mild steel sheet with robust steel framework sufficiently braced to prevent warping and twisting. The minimum sheet thickness shall be 1.2 mm for panels and 1.6 mm for doors. Other materials such as aluminium and stainless steel may be used subject to RailCorp approval.

The doors shall be fitted with removable-pin hinges and locking handles.

Opening doors shall have stops to prevent damage to doors or hinges from overswing.

3.2 Painting

3.2.1 Indoor Equipment

Where the supplier is able to provide a customised paint finish, outside surfaces of the cubicle shall be painted storm grey, colour No. N42 in accordance with AS 2700, in textured powder coat. The inside surfaces shall be painted white, colour No. N14 in accordance with AS 2700, in smooth powder coat. Cubicles that will be installed in corrosive environments shall be painted with a fit-for-purpose system rather than powder coat.

Where customised painting is not available, the supplier’s standard paint system and colour may be accepted subject to approval. However, the preferred colour for inside surfaces is white, colour No. N14.

3.2.2 Outdoor Equipment

Where external surfaces of outdoor equipment are to be painted, an approved paint system suitable for extended outdoor service shall be used. The paint system shall address:

• Surface preparation, including protection of threads and other vulnerable features, and treatment of difficult access parts.

• Masking of items that must be kept paint free.

• Timing, including time between surface preparation and the application of the first coat of paint, and the time between coats.

• Details of each coat to be applied including the type of coating, the method of application and the required dry film thickness.



• The repair scheme for minor damage.

• The applicable QA provisions.

3.3 Cable Entry

Floor mounted equipment shall be configured to accommodate cabling from both above and below.

Cable entries shall be designed for glanding of all control cables. Sufficient space in gland plates etc. shall be provided for the installation of at least two additional control cables in the future, and to accommodate cables with at least 15% spare cores.

3.4 Access

All controls, alarms, and indications shall be mounted for ready Operator access at the front of the cubicle.

Access to equipment, terminal strips and wiring for maintenance shall be unimpeded.

3.5 Lifting Points

Where appropriate, equipment shall be provided with lifting points suitable for slinging the equipment complete with all components installed.

3.6 Fixing Points

Fixing and mounting holes shall be welded or drilled and painted in the supplier’s works at locations to be shown on the general arrangement drawings.

All fixing and mounting holes shall be positioned to allow comfortable use of the appropriate tool during installation at site.

3.7 Colour Convention for Controls and Indications

3.7.1 1500V and High Voltage Devices

A red indication shall indicate that the switch is closed.

A green indication shall indicate that the switch is open.

A red control shall cause the switch to close.



A green control shall cause the switch to open.

Note: This colour requirement is the opposite of the convention as defined in Table 7.1 of AS 2067.

Figure 1

3.7.2 Low Voltage Devices

A red indication shall indicate that the switch is closed.

A green indication shall indicate that the switch is open.

A green control shall cause the switch to close.

A red control shall cause the switch to open.

3.8 Equipment Mounting

All control equipment and circuitry shall be mounted so that it is easily removable for maintenance. This may be achieved by the use of plug-in modules or an equivalent method.

3.9 Labelling

3.9.1 Language

All labelling shall be in the English language only.

3.9.2 Equipment Labels

All individual components and items of equipment shall be labelled by “Traffolyte” or similar material which shall remain legible over the life of the equipment when subjected to all reasonable mechanical wear and abrasion conditions.

Lettering shall be black letters on white background.

CLOSE

OPENPush Buttons Action:

O

CLOSEDD

Mechanical Indicator

= Circuit Breaker Open

= Circuit Breaker Closed



Labels shall be mounted on a fixed portion of the cubicle or compartment and not on the actual components, equipment or duct covers. Labels shall be positioned to remain visible after wiring and cabling are completed and so that components and equipment are not blocked from view.

Components and equipment mounted inside the cubicle or compartment shall be labelled with the schematic designation (eg “52OP”) in lettering of not less than 3 mm in height. Operator controls and equipment on the front panel shall be labelled with the device function (eg “Open ACCB”, “DCCB Closed”) in lettering not less than 4 mm in height. Stand-alone cubicles shall also be fitted with a main label inscribed with the name (eg “No. 1 Rectifier Control Cubicle”) in lettering of not less than 15 mm in height.

Specific labelling requirements for protection equipment are detailed in EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network.

3.9.3 Terminal Strip Labels

All terminals shall be clearly and indelibly labelled with the terminal number shown on the schematic diagram using proprietary labels from the terminal supplier.

3.9.4 Wire Identification & Numbering

All control and protection wires shall have a unique number and shall be identified at each end by white number ferrules inscribed in black characters with the wire number shown on the schematic diagram. Ferrules shall be a proprietary, interlocking type of size to match the wire diameter.

3.9.5 Cable identification codes for schematics, cable schedule and drawings

The identification codes for cables are to be used on all drawings, schedules and labeling are detailed in the table below:

ID Category Example application

CM COMMUNICATION OPTICAL FIBRE, COPPER SERIAL LINKS, PILOT CABLES, TELEPHONE, DATA

C CONTROL CONTROL CABLES BETWEEN PANELS.

FL FRAME LEAKAGE (RECT & DCCB)

DCCB FRAME TO FRAME LEAKAGE RELAY BAR, RECTIFIER TO RECTIFIER FRAME LEAKAGE RELAY.

E EARTHING EQUIPMENT EARTHS, EARTH GRID CONNECTIONS, HV CABLE SCREEN EARTHS



IA INSTRUMENTATION (ANALOGUE 0-20MA)

VOLTAGE & CURRENT TRANSDUCER OUTPUT CABLES, AMMETER & VOLTMETER CABLES

S SUPERVISORY SUPERVISORY INDICATION & CONTROL

AC <= 600V RECTIFIER TRANSFORMER 600V CABLES, AUXILIARY TRANSFORMER 600V CABLES, 415/240V POWER, 240V LIGHT

DC <= 120V BATTERY SUBMAINS

HV > 600V AC 2KV, 11KV, 33KV & 66KV

TP 1500V POSITIVE RECTIFIER 1500V POSITIVES, OHW FEEDER POSITIVES,

TN 1500V NEGATIVE RECTIFIER 1500V NEGATIVES, REACTOR TO TRACKSIDE BAR NEGATIVES, 1500V LINK RAIL CONNECTIONS, 1500V NEGATIVE LINK

TC TRACTION CONTROL REC, DCCB NEGATIVES, 1500V SURGE DIVERTERS , HARMONIC FILTER

CT CURRENT TRANSFORMER SECONDARY CABLES

CT CABLES FROM OUTDOOR SWITCHGEAR TO PROTECTION PANELS

VT VOLTAGE TRANSFORMER SECONDARY CABLES

VT CABLES FROM OUTDOOR VOLTAGE TRANSFORMER TO PROTECTION PANELS

PW Pilot Wire Pilot Wire

3.10 Auxiliary Supply Voltage

3.10.1 Traction Substation – DC auxiliary supply

Traction substations have dc auxiliary supply. For new and upgraded traction substations the nominal voltage is 125Vdc.

Equipment supplied at 125Vdc shall be designed to operate satisfactorily with the auxiliary voltage in the range 96 to 135V . All connected loads shall operate within this voltage range under ambient conditions as specified in section 3.20 Environmental and derating for enclosures as necessary.

Strategic traction substations have two independent dc auxiliary supplies. Criteria determining which substations have two dc supplies is specified in EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network.



3.10.2 Traction Substation – AC auxiliary supply

Traction substations have an ac auxiliary supply. For new and upgraded traction substations the nominal voltage is 3-phase 415/240 Vac.

Equipment supplied at 415/240 Vac shall be designed to operate satisfactorily with the auxiliary voltage in the range -20% to +20% of this nominal voltage.

3.10.3 DC auxiliary supply – other than traction substations

DC auxiliary supply for equipment in sectioning huts, HV AC switching substations and other locations can be 125 or 48 Vdc nominal. At locations with 48V dc, equipment must be designed to operate satisfactorily with the auxiliary voltage in the range 43 to 58 Vdc.

3.10.4 AC auxiliary supply – other than traction substations

Requirements for equipment operating in sectioning huts, HV AC switching substations and other locations requiring ac auxiliary supplies will be provided in future versions of this standard.

3.11 Wiring

3.11.1 General

All wiring shall be installed to the requirements of AS 3000 and equipment supplier specifications.

All 125 Vdc wiring (other than control wiring installed on 1500 Vdc equipment) shall be able to withstand a 1 minute test voltage of 1.5 kV rms to earth.

Requirements for control wiring installed on 1500 Vdc equipment such as DCCB’s and rectifiers are detailed in the respective RailCorp equipment specifications.

DC control wiring and the AC auxiliary supply wiring shall be segregated.

The requirements of this section need not apply to special purpose signal and electronic wires.

On terminal blocks, intermeshing of cores of different field cables will not be accepted.

Current and voltage transformer wiring shall be as specified in EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network

Wiring to swing-frames and doors shall be suitably formed to sustain the flexing imposed and properly protected from damage.



3.11.2 Termination

All wires shall be terminated using proprietary crimp lugs (not bootlaces) of correct size for the conductor. Lugs shall be the insulated barrel type. Termination of protection wiring at the relay shall be by screwed connections using ‘ring’ type crimp lugs as recommended by the relay manufacturer.

Not more than two wires shall be terminated in any tunnel-type terminal.

3.11.3 Minimum Wire Size and Wire Type

Small wiring shall generally be stranded copper 0.6/1 kV or 0.45/0.75 kV V-90HT PVC insulated. Unless noted otherwise on the schematic diagrams, DC control wiring shall be 1.5 mm2 cross-section, flexible, multi-strand copper (30/0.25).

3.11.4 Wire Colours

Colours for dc control wiring shall be brown for positives, light blue for negatives and grey for all mid-wires. “Mid-wires” means all wires that are more than one device away from the positive and negative rails of the control circuit, where a “device” is a relay or switch contact, coil, indicating light etc.

Colours for ac and dc power wiring shall be in accordance with AS 2067.

CT and other protection wiring shall be as specified in EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network.

3.12 Terminal Blocks

Small wiring field terminals shall generally be the rail-mounted, spring-loaded tunnel type. Terminals shall be grouped according to function and voltage and groups shall be segregated by proprietary barriers. Terminals energised at 415 and 240 Vac shall be shrouded and denoted as hazardous by warning labels.

Terminal numbers shall be allocated on the schematic diagrams so that all the cores of each field cable can be terminated on consecutive terminals.

The terminal block shall include 15% spare terminals, or a minimum of one (1), whichever is the larger, for each cable to be terminated.

CT and VT secondary wiring terminals shall be as specified in EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network.



3.13 Earth terminal

Equipment intended to be located in substations shall be provided with an earth terminal suitable for connection of an earth cable of a minimum size of 70 mm2.

3.14 Light

An appropriate 240 Vac light fitting shall be installed in the cubicle or assembly to illuminate areas containing equipment and terminal strips where the design is such that this equipment will not be directly illuminated by external lighting. The light shall be activated by a switch on the front panel, or automatically when the door is opened.

3.15 Auxiliary Relays, Push Buttons, and Selector Switches

3.15.1 Contacts

Contacts of auxiliary relays, push buttons, and selector switches used at ELV, low current shall be designed for such duty. Particular attention shall be given to ensuring contact wetting by means of gold plated contacts, wiping contacts or other suitable means.

3.15.2 Relays

All relays shall have clear and ready visual indication of the state of the relay, either by direct observation of the mechanism (flag) or by means of a LED.

Plug-in relays are preferred.

All plug-in relays shall be positively retained in their bases.

3.15.3 Suppression Diodes

Suppression diodes shall be provided across DC coils where appropriate to limit back EMF in order to protect contacts and/or reduce EMR.

3.15.4 Trip Circuit Supervision

Where Trip Circuit Supervision is employed, continuity of the circuit shall be monitored as well as availability of the power supply.

The Trip Circuit Supervision (TCS) relay shall be connected, physically, to the end point of the wires in the trip circuit. ie The tripping circuit is to be made by looping all wires right onto the terminals of each tripping contact, with the TCS relay furthest from the supply fuses or circuit breaker. In this way, a break in the wiring of this circuit will be detected.



The TCS relay shall drop out (providing indication to SCADA) before the voltage measured at the end point of the circuit wiring falls to the minimum operating level of the control relays. (SCADA indication is required based on the control relays’ capabilities). It is acceptable that the indicating LED’s have stated minimum operating voltages different to this threshold.

Refer to EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network for details of approved TCS relays.

3.15.5 Indicator Lights

All indicator lights shall be LED types.

The colour of indicating lights shall be identified on schematics by placing an appropriate letter adjacent to the LED: G – green, R – red, W – white.

3.16 Programmable Equipment

Programmable controllers used in Electric Power Equipment shall be the product of a recognised supplier and be purpose-built to carry out the functions specified. Programming shall be carried out using non-proprietary, commonly available and inexpensive equipment and software and shall be possible by downloading from storage medium or entering via keypad and display unit mounted on the front of the cubicle or compartment.

Operator control and interrogation shall be possible via the keypad and display unit. Access to keypad control functions and programming shall be restricted by password. Indications of status shall be continuous and immediately apparent without the need to use the keypad.

The controller shall include means of retaining programming for one year in the event of loss of auxiliary power.

3.17 Current Transformers

Current transformers shall be as detailed in EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network.

3.18 Metering

Where required, analogue display meters for indication purposes shall be between 96 mm and 144 mm square and comply with AS 1042 with an accuracy class of 2.5.

Meters shall be mounted with the bottom not lower than 500 mm above floor level and the top not higher than 2000 mm above floor level.



3.19 Selection of Components and Equipment

The make and model of components and equipment used shall generally be as nominated on the schematic diagrams. However, approved equivalents may be used provided that these are readily available items from recognised suppliers.

3.20 Environmental

The ambient temperature rating and degree of protection to AS 60529 shall be as required by RailCorp Standard EP 00 00 00 13 SP, Electrical Power Equipment – Design Ranges of Ambient Conditions. The equipment supplier shall make due allowance for the temperature rise that can occur within a panel or assembly when specifying the ambient rating of components used in that panel or equipment assembly.



4 Maintenance Concept

The equipment supplied must be suitable for operation with only limited periodic routine maintenance comprising tasks falling into the following categories as applicable:

• Testing of functionality

• Injection testing of any protection relays

• Cleaning

• Lubrication of locks and hinges.

• Replacement of circuit breaker contacts.

• Calibration

• Checking of gas pressure

• Oil sampling

These tasks shall be Level 1 (on system). Level 2 (off system) tasks are generally not acceptable for periodic routine maintenance. Where it is not practical to undertake major corrective tasks on system, a level 2 off system approach will be acceptable.



5 Testing

5.1 Type Tests

All protection relays, electronic modules and controllers shall be type tested in accordance with the relevant standards.

5.2 Routine Tests

Routine factory tests shall include the following as applicable to the equipment concerned:

• Inspection in accordance with AS 3439.1 Clause 8.3.1.

• Continuity (point-to-point) test of all wiring.

• Dielectric test at power frequency in accordance with AS 3439.1 Clause 8.3.2 or AS 2067 Clause 11.3.1 as appropriate.

• Function test of all logic and interlocks.

• Secondary injection testing of protection relays and metering.

• Polarity (flick) test of CTs and VTs.

• Group primary injections of CT’s.

• Phasing of power circuits.

Copies of final inspection and equipment routine test reports shall be provided and comply with EP 00 00 00 12 SP, Electrical Power Equipment – Integrated Support Requirements.



6 Data Set Associated With The Equipment

The following data shall be provided when relevant by the equipment supplier and maintained for the life of the equipment. This data shall remain the property of RailCorp.

6.1 Drawings

6.1.1 Drawings Required

• General arrangements, giving cubicle dimensions and showing the location of all relays, operator controls, terminal blocks and other devices along with the entry points of all cables. General arrangement views to include front, floor plan and end. Sheet metal fabrication details of cabinets showing material type and thickness, surface preparation and paint finish details shall be provided.

• Single line diagram.

• Functional block diagram.

• Schematic diagrams of all circuitry, including a legend sheet listing all device identifiers with their full description and giving their locations on the schematics.

• Component schedule listing the device schematic identifier, description, supplier, model number, ratings if relevant and the location on the schematic diagram. (This may be integrated with the schematic diagrams legend sheet).

• Cable / termination schedule giving cable number, core number, wire number, origin and destination, origin and destination terminal numbers, function of each core, number of cores in cable, conductor material and cross-section, insulation grade, screen type if applicable, insulation and sheath material and any relevant comments. RailCorp template in excel format is available and is the preferred method of documentation. See section 2.5 RailCorp Templates.

• Cabling block diagram.

• Terminal block layout.

• Where programmable controllers are included, provide full functional specification of the control logic, fully annotated logic diagrams, factory and site acceptance tests and, if available, source code for any custom-built software.



• SCADA I/O list

6.1.2 Manufacturers Standard Drawings

The manufacturers standard drawings for an item of equipment will be acceptable where they :

• Accurately represent the equipment supplied

• Provide all required information

• Are presented on sheets not larger than A1

• Are provided in the English language

• Use symbols in accordance with AS 1102.

6.1.3 Project Drawings

6.1.3.1 CAD Drafting

All drawings shall be produced in accordance with the RailCorp specification ED 0024P, CAD and Drafting Manual – Electrical.

The sheet size shall not be larger than A1.

All drawings will be stored within the RailCorp drawing system in Microstation format, the preferred format for drawings being Microstation Version 8, however RailCorp will accept drawings produced in AutoCAD Version 2000.

To minimise the complications arising from conversion from AutoCAD to micro station & vice versa the following shall be observed:

• Copy & rename suitable size RailCorp provided border sheet. Border sheets for sizes A1 to A3 with scales of 1:100, 1:50, 1:20 & 1:1 are available.

• use the renamed file to draw and annotate.

• For linework, draw in modelspace at 1:1 scale, units are in mm.

• For annotation, draw in modelspace at 100 times (eg. to get a printed text size of 2.5mm, draw at text size of 250mm).

• Do not attach xref's. If you do, merge them & detach xref's.

• Do not use paperspace.

• Do not use viewports.



• Use one scale only in one drawing. Xref’s and viewports should not be used.

• Use isocp3.shx as font file with width factor of 1.05

• Do not use shared cells.

The border sheet has elements on level 60. Do not draw anything on this level; do not delete anything from this level (if needed please consult RailCorp). Do not move the border area. The final printed size is determined by the master drawing sheet, which can be A1, A2, A3 or A4 dependent upon content. For additional information see Appendix C.

6.1.3.2 Schematic Diagrams

Symbols used in drafting schematic diagrams shall be in accordance with AS 1102-1997

Components on the schematic and other drawings must be designated according to the RailCorp identifiers tabled in Appendix A. Where there is no RailCorp identifier for a particular device, it shall be designated according to IEEE standard C.37.2 – 1996.

Schematics shall employ a column reference system for locating devices. The location of each relay contact and device auxiliary contact shall be shown near the relay or device on all schematics.

Every connecting line or group of lines in a control or protection circuit shall be identified with a wire number on the schematic. The numbering system used shall conform to that given in Appendix D of AS 2067 – 1984 except that positive rails shall be designated BP# (for battery positive 1, 2, 3 etc) and negative rails shall be designated BN#.

Connecting lines that pass between separate equipment cubicles shall be drawn dashed to highlight that they are “field” connections. Terminal symbols shall be in accordance with Figure 2 and shall be shown at the ends of each such line.



Figure 2 – Drawing Terminal Symbols

All terminals shall be designated with a prefix letter consistent with the broad function of the circuit, followed by a two or three digit number. The prefixes to be used are “C” for DC control and protection, “CT” for current transformer secondaries and “S” for connections to SCADA.

6.2 Test Results

The results of all tests, including Routine, Type and corrective maintenance tests, shall be recorded and maintained.

Routine test certificates showing the results of each test performed shall be supplied in duplicate and electronically, in English, and maintained for the life of the equipment.

Type test certificates for each protection relay and electronic module shall be supplied in duplicate, in English, and maintained for the life of the equipment.

RECTIFIER CONTROL CUBICLE TERMINAL

ACCB TERMINAL

DCCB PLUG PIN/SOCKET

DCCB TERMINAL BOX CONNECTOR

RECTIFIER TRANSFORMER TERMINAL

RECTIFIER TERMINAL

DC REACTOR TERMINAL

FIELD CABLE CORE



7 Appendices

Appendix A Schematic Diagram Identifiers.............................................................. 27

Appendix B Request for Tender Checklist ............................................................... 31

Appendix B.1 Application .......................................................................................................................31 Appendix B.2 Information to be supplied to the Tenderer ..................................................................31 Appendix B.3 Information to be provided by equipment suppliers ...................................................33

Appendix B.3.1 Label Schedule 33 Appendix B.3.2 Inspection and Test Plan 33 Appendix B.3.3 Drawings 33

Appendix C AutoCAD to Microstation Specifications ............................................. 35



Appendix A Schematic Diagram Identifiers

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 Typical Location

8LX Auxiliary CB Trip Relay

33-1 Negative Isolator Accessed Switch Rectifier

43 Local/Supervisory Changeover Switch (L - Local S - Supervisory)

Rectifier CC

43A Local/Remote Changeover Switch ACCB ACCB

50A Instantaneous Overcurrent Relay (A phase) Rectifier CC

50C Instantaneous Overcurrent Relay (C phase) Rectifier CC

51A Inverse Time Overcurrent Relay (A phase) Rectifier CC

51C Inverse Time Overcurrent Relay (C phase) Rectifier CC

51A2 Overcurrent Breaker Fail Relay (A phase) Rectifier CC

51B2 Overcurrent Breaker Fail Relay (B phase) Rectifier CC

51C2 Overcurrent Breaker Fail Relay (C phase) Rectifier CC

51AX Auxiliary Overcurrent Relay (A phase)

51CX Auxiliary Overcurrent Relay (A phase)

51X Auxiliary Relay for Rectifier Breaker Fail Protection Rectifier CC

52 ACCB ACCB

52C ACCB Closing Contactor ACCB

52CC ACCB Closing Coil ACCB

52H ACCB Heater Control Switch ACCB

52M ACCB Closing Motor ACCB

52M ACCB Closing Springs Charge Motor ACCB

52MC Spring Charging Limit Switch ACCB

52OP ACCB Open Auxiliary Relay Rectifier CC

52R ACCB Heater Coil ACCB

52SO Solid State Open Device

52T ACCB Trip Coil ACCB

52t ACCB Heater Thermostat ACCB

52 Close ACCB Close Push Button Rectifier CC




52 Open ACCB Open Push Button Rectifier CC

54 DCCB DCCB

54A DCCB Auxiliary Relay

54a DCCB Operating Auxiliary Switch DCCB

54C DCCB Closing Coil DCCB

54D Auxiliary Relay for Reverse Current Trip DCCB

54ES DCCB Closing Motor Limit Switch DCCB

54H DCCB Holding Coil DCCB

54M DCCB Closing Motor DCCB

54R DCCB Reverse Current Trip Indication Relay DCCB

54S DCCB Stabilising Coil DCCB

54T DCCB Delayed Closing Relay

54US Mechanically Interlocked Limit Switch DCCB

54UV DCCB Undervoltage Coil DCCB

54X DCCB Closing Coil Contactor DCCB

54XX Auxiliary Relay for Closing Coil

54Y DCCB Auxiliary Relay for De-engergising Closing Coil

DCCB

54Z DCCB Auxiliary Relay

54 Close DCCB Close Push Button Rectifier CC

54 Open DCCB Open Push Button Rectifier CC

63-1 Buchholz Gas Contact Rect. Transf.

63-2 Buchholz Oil Contact Rect. Transf.

63RX DC Reactor Overpressure Follower Relay DC Reactor Overpress Pnl

63RY DC Reactor Overpressure Auxiliary Relay Rectifier CC

63X Auxiliary Relay for Buchholz Oil Rectifier CC

63Y Auxiliary Relay for Buchholz Gas Rectifier CC

64 Instantaneous Earth Fault Relay Rectifier CC

64-2 Earth Fault Breaker Fail Relay Rectifier CC

64E Rectifier Frame Leakage Relay Rectifier




64EX Auxiliary Relay for Rectifier Frame Leakage Rectifier CC

71 Rectifier Cell Fail Relay Rectifier CC

75 DCCB Door Switch Interlock DCCB

77CAP Rectifier Transformer Primary Current Transducer Rectifier CC

77CD Rectifier Output Current Transducer Rectifier

77TI Rectifier Inlet Air Temperature Transducer Rectifier

77TO Rectifier Outlet Air Temperature Transducer Rectifier

77VD Rectifier Output Voltage Transducer Rectifier

84-1 Tap Change In Progress Signal Contact Rect. Transf. Tapchanger

84-2 Tapchanger Fault Rect. Transf. Tapchanger

84Y Tap Change In Progress Auxiliary Relay Rectifier CC

86 Rectifier Lockout Relay Rectifier CC

86A DCCB Frame Leakage Relay. Rectifier CC

86AX DCCB Frame Leakage Auxiliary Relay Rectifier CC

86PB Rectifier Lockout Relay Reset Push Button Rectifier CC

89 Air Break Switch

89G Negative Isolator Rectifier

89G-1, -2 Negative Isolator Limit Switch Rectifier

89GR Negative Isolator Auxiliary Relay Rectifier CC

94 ACCB Anti-pumping Relay ACCB

94D DCCB Anti pumping Relay

97 Sequence Timing Relay

97X Auxiliary Relay for Reverse Current Trip Rectifier CC

305A ACCB Supervisory Close Relay ACCB

306A ACCB Supervisory Open Relay ACCB

FS DCCB 1500 V 3 A Fuse DCCB

ILS Indicating Light Switch Rectifier CC

LCS1 ACCB Local Control Switch (T – Trip N – Normal C – Close)

ACCB




MTA Multi Trip Auto Reset Relay (Follows 51A2, 51B2, 51C2 & 64-2 and trips all 33 kV ACCBs – all sources of power)

Rectifier CC

TBK1, 2 Test Block Rectifier CC

TCS Trip Circuit Supervisory Relay Rectifier CC

TL DCCB Test Link DCCB

TM Charge Motor Timer

Xn Link Terminal

The colour of indicating lights shall be identified on schematics by placing an appropriate letter adjacent to the LED: G – green, R – red, W – white.



Appendix B Request for Tender Checklist

Appendix B.1 Application

The following material is for guidance in the preparation of a Request for Tender (RFT) for this type of equipment. This checklist itself is not intended to directly form part of any contract.

Appendix B.2 Information to be supplied to the Tenderer

Where this document is used as the basis for procurement of equipment for a particular location, in addition to the general requirements in this standard the following information related to the particular site will need to be supplied:

• A full list of deliverables required under the contract including:

• Number of sets of equipment required.

• Support Equipment and Tooling.

• Number of sets of Documentation required.

• Training Required.

• DC auxiliary voltage.

• AC auxiliary voltage.

• Any site specific limitations on size or arrangement.

• Any site specific corrosion protection requirements such as suitability for coastal installation.

• Colour requirements for outdoor equipment as might be required to match existing equipment or meet requirements of a local authority.

• Limitations due to access or transport.

• Details of interfacing equipment supplied by RailCorp, including schematic diagrams, general arrangement drawings and manufacturer’s data.

• The pricing methodology to be applied for selection of equipment. This must be made on the basis of minimising the whole-of-life cost. The following factors must be considered in determining this:

• Cost of changes to the Technical Maintenance Plan & Service Schedules or the creation of new manuals & schedules.



• Initial purchase price.

• Cost of installation.

• Cost of inventory spares.

• Cost of maintenance.

• Cost of manuals.

• Cost of modifications to other parts of the installation.

• Cost of replacement parts.

• Cost of special tools.

• Cost of staff training.

• Electrical losses.

• Environmental costs.

• Reliability and cost of consequential damage after failure.

• Cost of decommissioning and disposal.

• Discount rate.

• Lifetime of equipment.

• Tenderers should be advised that the cable / termination schedule and cabling block diagram specified at section 6.1.1 Drawings Required are not required for contracts including only supply of equipment.

• The tenderers should be advised that at the time of publication of this document, the editions of reference standards indicated were valid. All standards and specifications are subject to revision, and parties to agreements based on this specification are encouraged to investigate the possibility of applying the most recent editions of the reference standards.

The RFT document shall have a section on preparation of equipment for shipment. The main points are:

• All equipment shall be suitably packed for protection against damage during loading, transport, storage and unloading.

• Equipment subject to damage due to vibration such as plug-in relays, printed circuit boards and the like shall be removed and separately packed in clearly marked containers.



• Equipment packed separately or sectionalised for installation shall be provided with all assembly fittings, accessories and instructions.

Appendix B.3 Information to be provided by equipment suppliers

Type Test certificates for evaluation, QA management certificates, sample ITP and ITC, tentative manufacture and delivery programme, typical GA drawing, data sheets and pamphlets, information listed in B2 that is required for estimation of whole-of-life cost.

Appendix B.3.1 Label Schedule

Attention must be drawn to the requirement for the equipment supplier to provide a Label Schedule. The Label Schedule shall list all labels required and shall detail wording, letter size and label size.

Appendix B.3.2 Inspection and Test Plan

Attention must be drawn to the requirement for the equipment supplier to provide an Inspection and Test Plan (ITP) and associated Inspection and Test Checklist (ITC). This must include the time after the placement of the order by which the draft ITP and ITC must be submitted for approval.

The ITP must nominate hold points for witness tests and inspections. The amount of notice required regarding the approach of each such hold point must be stated.

Appendix B.3.3 Drawings

Each revision of every drawing during design and manufacture shall be submitted for review by RailCorp. One print marked with any necessary comments will be returned to the equipment supplier within fifteen (15) working days of receipt by RailCorp. The comments shall be considered by the equipment supplier and incorporated in the next revision of the drawing. The required timing for the initial submissions of each drawing must be stated in the RFT.

“As-Built” versions of each drawing shall be submitted no later than the time of delivery of the equipment.

Each drawing revision forwarded to RailCorp shall be submitted in the following forms:

• Three (3) full-size paper prints

• Electronic copy in Microstation Version 8 or AutoCAD Version 2000 format.



• Electronic copy of each approved drawing in TIFF MSB, Monolithic CCIT Group IV file format, non colour drawings - resolution 300dpi in both X & Y directions.

All submissions shall be accompanied by a transmittal form listing all drawings being forwarded and stating the drawing revisions. The transmittal shall be signed and dated by a responsible representative of the Contractor.

The Component Schedule (refer section 6.1.1 Drawings Required) shall be subject to approval by RailCorp.



Appendix C AutoCAD to Microstation Specifications

AutoCAD MICROSTATION

LAYER FONT COLOR WEIGHT LINESTYLE LEVEL FONT COLOR WEIGHT LINE CODE

BORDER TEXT & LINE 60 60

TITLE TEXT 59 ROMANC WHITE - CONTINUOUS 59 137 0 1 0

GENERAL TEXT 2.5mm 8 ROMANS WHITE - CONTINUOUS 8 138 0 1 0 GENERAL TEXT 3.5mm 8 ROMANS RED - CONTINUOUS 8 138 3 2 0 GENERAL TEXT 5.0mm 8 ROMANC GREEN - CONTINUOUS 8 137 2 3 0

EQUIPMENT/HARDWARE 1 - WHITE - CONTINUOUS 1 - 0 1 0 EQUIPMENT/HARDWARE 3 - MAGENTA - DASHED 3 - 5 0 2 EQUIPMENT/HARDWARE 4 - MAGENTA - CENTRE 4 - 5 0 4

MAJOR 5 - RED - CONTINUOUS 5 - 3 2 0 5 - RED - DASHED 5 - 3 2 2

CABLES, CONDUITS AND 12 - SEE - SEE TABLES 12 - VARIOUS VARIOUS VARIOUS BUILDING 20 - SEE - SEE TABLES 20 - VARIOUS VARIOUS VARIOUS

TEXT/LINEWORK FOR BILL 21 ROMANS WHITE - CONTINUOUS 21 138 0 1 0

EARTHWORK & OTHER 22 - SEE - SEE TABLES 22 - VARIOUS VARIOUS VARIOUS



FONT MAPPING BETWEEN AutoCAD & MICROSTATION AutoCAD MICROSTATION

ROMANS 139

ROMAND 138

ROMANC 137

LINE STYLES MAPPING BETWEEN ACAD & MICROSTATION. LTSACLE TO SUIT AutoCAD. LTSCALE IS IRRELEVANT IN

MICROSTATION AutoCAD MICROSTATION

CONTINUOUS 0

DASHED2 1

DASHED 2

DASHEDX2 3

CENTRE 4

HIDDEN 5

PHANTOM 6

COLOR MAPPING BETWEEN AutoCAD & MICROSTATION. PLEASE SEE THAT CHOOSING A COLOR IN AutoCAD AFFECTS BOTH

COLOR & WEIGHT AT THE SAME TIME AutoCAD MICROSTATION

COLOUR PEN THICKNESS COLOUR WEIGHT RED (1) 0.35 3 2

YELLOW (2) 4 -

GREEN (3) 0.50 2 3

CYAN (4) 1 -

DARK BLUE (5) 0.70 9 4

MAGENTA (6) 0.18 5 0

WHITE (7) 0.25 0 1

Copy No.


Discipline

Electrical Engineering Specification

Category

High Voltage AC Switchgear

Title

11kV AC Indoor SCADA controlled switchgear fitted with stationary (non withdrawable) switching devices Reference Number


2.0

Date of Issue

JUNE 2007

Status

Approved

Electrical Engineering Specification: High Voltage AC Switchgear 11kV AC Indoor SCADA controlled switchgear fitted with stationary (non withdrawable) switching devices EP 01 00 00 02 SP


Prepared by

NEAL HOOK, Principal Engineer, Power Systems Engineering Standards & Services Division

Reviewed by

David Stuart-Smith, Chief Engineer, Electrical Systems Engineering Standards & Services Division Chris Lilly, Technical specialist, Electrical Systems Engineering Standards & Services Division

Approved by


Revision Summary



1.0 21/06/2007 First Issue


See Revision History on page 16 for a full listing of the document changes.



DISCLAIMER

Rail Corporation of New South Wales has used its best endeavours to ensure that the content, layout and text of this document is accurate, complete and suitable for it’s stated purpose. It makes no warranties, express or implied, that compliance with the contents of this document shall be sufficient to ensure safe systems of work or operation. RailCorp will not be liable to pay compensation in respect of the content or subsequent use of this document for any other purpose than its stated purpose or for any purpose other than that for which it was prepared except where it can be shown to have acted in bad faith or there has been willful default.

DOCUMENT APPROVAL







COPYRIGHT




About This Standard

This document details the whole of life performance requirements for indoor 11kV non-withdrawable switchgear for use in the RailCorp distribution system. All information required to ensure that the switchgear is electrically suitable for the RailCorp network is contained in this document or referenced by this document.

Switchboard units of various configurations are fitted with SCADA controlled circuit breaker and load break fault make switch panels complete with interlocked make-proof earthing facilities combined and arranged in linear configurations.

The normal arrangement whereby a busbar and associated switchgear is to be sectionalised into two or more sections is accomplished by each section comprising a separate switchboard unit, physically separated from the other unit(s) and connected by a tie cable through a bus tie circuit breaker at each end of the tie cable.

Where space or building constraints (cable ducts etc) exist a bus coupling circuit breaker arrangement maybe required for the busbar sectionalising function – this is not a preferred configuration.

Specific circuit breaker panel configuration requirements are set out for the following applications: feeder, bus tie, transformers and capacitors. Some configurations will require switch disconnector functional units. The protection and control equipment is an integral part of the switchboard and located with the associated switchgear. Specific details of the required protection schemes and associated equipment are provided in a companion document, EP 19 00 00 02 SP “Protection System requirements for the High Voltage network”. The requirements of this protection document must be complied with in the supply and use of 11kV switchgear specified herein.

Busbar voltage transformers shall be provided for each busbar in each switchboard.

This standard does not apply to ring main units.



Table of Contents

1 Scope and Application ............................................................................ 8

1.1 General................................................................................................................................8 1.2 Application .........................................................................................................................9

2 References.............................................................................................. 10

2.1 International Standards...................................................................................................10 2.2 Australian Standards.......................................................................................................10 2.3 RailCorp Standards .........................................................................................................11

3 Definitions, Terms and Abbreviated Terms ......................................... 13

3.1 Definitions and Terms.....................................................................................................13 3.2 Abbreviated terms: ..........................................................................................................14

4 Revision History..................................................................................... 16

4.1 Version 1.0........................................................................................................................16 4.2 Version 2.0........................................................................................................................16

5 Background ............................................................................................ 17

6 Functional Characteristics .................................................................... 18

7 Performance Characteristics ................................................................ 19

7.1 General..............................................................................................................................19 7.2 Busbar...............................................................................................................................21

7.2.1 High impedance bus zone protection 22 7.2.2 Internal arc fault detection scheme 22

7.3 Bus tie cable circuit breaker...........................................................................................22 7.4 Bus coupling circuit breaker ..........................................................................................24 7.5 Feeder Circuit Breaker ....................................................................................................25 7.6 System transformer (incomer) circuit breaker .............................................................26 7.7 Distribution transformer (outgoing) circuit breaker ....................................................28 7.8 Capacitor / harmonic filter circuit breaker ....................................................................29 7.9 Feeder circuit breaker (Non Auto) .................................................................................32 7.10 Feeder network switch (Supervisory Indication only) .................................................33

8 Technical Characteristics...................................................................... 34

8.1 General..............................................................................................................................34 8.2 Switchboard Configurations...........................................................................................34

8.2.1 Supply Point switchboard configurations 34 8.2.2 Switching Station switchboard configurations 35 8.2.3 System substation switchboard configurations 35 8.2.4 Mid point switching switchboard configuration 36



8.2.5 Bus coupled circuit breaker switchboard 36 8.2.6 Example switchboard configurations 36

8.3 Rated Insulation Level.....................................................................................................50 8.4 Control Voltage – DC auxiliary supply voltage.............................................................50 8.5 Busbar...............................................................................................................................51 8.6 Gas insulation (where applicable) .................................................................................51

8.6.1 Pressure relief for gas compartments 52 8.6.2 On-site installation and possible extension 52 8.6.3 Current transformers 52 8.6.4 Voltage transformers 52 8.6.5 End of life gas recovery 53

8.7 Earthing bar......................................................................................................................53 8.8 Current Transformers......................................................................................................54

8.8.1 CT rating plate 54 8.9 Voltage Transformers......................................................................................................54

8.9.1 General 54 8.9.2 Directional Protection Supply Alarm 54 8.9.3 Voltage Transformer Alarm 54

8.10 Low voltage cabinet ........................................................................................................55 8.11 Circuit-Breakers...............................................................................................................55

8.11.1 General 55 8.11.2 Circuit Breaker Type 55 8.11.3 Circuit-breaker operating mechanisms 56 8.11.4 Circuit-breaker Operation and Control 56

8.12 Indication..........................................................................................................................57 8.13 Auxiliary Equipment ........................................................................................................57 8.14 Interlocks..........................................................................................................................58 8.15 HV Cable Interface ...........................................................................................................60

8.15.1 General 60 8.15.2 Fully insulated cable terminations 60 8.15.3 Non fully insulated cable terminations 60 8.15.4 Cable compartment size 61

8.16 Surge arresters ................................................................................................................61 8.17 Circuit Earthing Facilities ...............................................................................................61 8.18 Voltage detecting system ...............................................................................................62 8.19 Circuit Test Facilities.......................................................................................................62 8.20 Padlocking........................................................................................................................62 8.21 Floor fixing and penetration details...............................................................................63 8.22 Segregation of LV wiring in HV compartment ..............................................................63 8.23 Instruments, Transducers and Metering .......................................................................63



8.23.1 General 63 8.23.2 Current transducers 64 8.23.3 Voltage transducers 64 8.23.4 Ammeters 64 8.23.5 Voltmeters 64 8.23.6 Watthour meter 64

8.24 Busbar and Circuit Protection........................................................................................65 8.24.1 General 65 8.24.2 Feeder Protection 65 8.24.3 System Transformer Protection 65 8.24.4 Distribution Transformer Protection 65

8.25 SCADA Indications and Controls...................................................................................66 8.25.1 Binary Indication & ACCB Control 66 8.25.2 Analogue Indication 66 8.25.3 Controls 67

9 Integrated System Support Requirements .......................................... 68

9.1 Integrated Support Objectives .......................................................................................68 9.2 Equipment Supplier Deliverable ....................................................................................68

10 Tests........................................................................................................ 69

10.1 Routine tests ....................................................................................................................69 10.2 Type tests .........................................................................................................................69

11 Data Set associated with the Equipment ............................................. 70

11.1 Information .......................................................................................................................70 11.2 Technical Schedule at Appendix A................................................................................70 11.3 Life Cycle Costing ...........................................................................................................70

Appendix A Technical Schedule................................................................................ 71

Appendix B RFT Checklist ......................................................................................... 84

Appendix B.1 Application .......................................................................................................................84 Appendix B.2 Information to be Sought From the Tenderer ...............................................................84 Appendix B.3 Information to be supplied at time of order ..................................................................85




1.1 General

This document specifies the characteristics of factory assembled, type tested, metal –enclosed, single busbar, fixed (stationary) switching devices designed for indoor installation on railway distribution systems operating at nominal 11kV A.C., three-phase, 50 Hz.

The requirement is for switchboards of up to nine SCADA controlled circuit breaker panels suitable for deployment in linear configurations.

Where two or more busbar sections are required at a substation each section will comprise a separate Switchboard Unit, physically separated from the other unit(s) and connected by a tie cable through a tie circuit breaker at each end of the tie cable. Specific switchboard functional units may include:

• feeder ACCB,

• bus tie cable ACCB,

• bus coupling ACCB,

• system transformer (66kV/11kV and 33kV/11kV) ACCB, (incomer)

• distribution transformer (11kV/415) ACCB,

• harmonic filter or capacitor bank switching ACCB

• feeder network load switch

The switchgear panels will in general each include equipment that comprises a fixed functional unit, with an associated off-load disconnector and interlocked earthing facility, in combination with the associated SCADA control, measuring, indicating, alarm, and protective equipment, including interconnections, accessories, enclosures and supporting structure.

The protection equipment is located in or immediately above the relevant circuit breaker panel. Details of the required protection schemes are specified in RailCorp standard EP 19 00 00 02 SP – Protection System Requirements for the High Voltage Network. The switchboard shall incorporate the applicable requirements of EP 19 00 00 02 SP.

Busbar voltage transformers are required for all switchboard units.

The switchgear is for indoor use under ambient conditions as specified in RailCorp standard EP 00 00 00 13 SP.



1.2 Application

The requirements of this document apply when a new 11kV indoor switchboard is purchased or installed in a RailCorp substation from the date of issue that this specification is approved.

The requirements of this document are not applicable to existing 11kV indoor switchboards currently in service in the RailCorp network.



2 References

The following documents contain provisions, which, through reference in this text, constitute provisions of this Standard.

At the time of publication, the editions indicated were valid.


Standard Title

IEC 61243-5 Voltage detection systems

Table 1 – International Standards



Standard Title

AS 1018 Recommendations for partial discharge measurements

AS 1265-1990 Bushings for Alternating Voltages above 1000V

AS 1852.441-1985 International Electro technical Vocabulary. Chapter 441: Switchgear, control gear and fuses

AS 1931.1 High voltage test techniques, Part 1. General definitions and test requirements (Identical to IEC 60060-1)

AS 2067-1984 Switchgear assemblies and ancillary equipment for alternating voltages above 1 kV

AS 2629 – 1983 Separable insulated connectors for power distribution systems above 1kV

AS 2650-2005 Common specifications for high-voltage switchgear and control gear standards, (IEC 60694 Ed.2.2(2002) MOD)

AS 2700-1996 Colour Standards for General Purposes

AS 2791-1996 High voltage A.C. switchgear and controlgear – Use and handling of SF6 in high voltage switchgear and controlgear (Identical to IEC 61634)

AS 3760-2003 + Amd 1 - 2005

In service Safety inspection & testing of electrical equipment



Standard Title

AS 1675 - 1986 Instrument transformers - Current Transformers

AS 1243 - 1986 Instrument transformers - Voltage transformers

AS 60265-2001 High-voltage switches - Switches for rated voltages above 1 kV and less than 52 kV

AS 60417(all parts) Graphical symbols for use on equipment (identical to IEC 60417)

AS 60529 - 2004 Degrees of Protection Provided by Enclosures (IP Code).

AS 62271.100 – 2005

High Voltage A.C. Switchgear and Controlgear - Part 100 High voltage alternating-current circuit Breakers breakers

AS 62271.102 – 2005

High voltage A.C. switchgear and controlgear - Part 102 Alternating Current Disconnectors (isolators) and earthing switches

AS 62271.200 – 2005

High voltage switchgear and control gear - Part 200 AC metal enclosed switchgear and controlgear for rated voltages above 1kV and up to and including 52kV

AS 62271.301 – 2005

High voltage switchgear and control gear - Part 301 Dimensional standard of terminals

AS K126 Full gloss enamel, oil and petrol resistant

AS ISO 9001 Quality systems requirements

Table 2 – Australian Standards

2.3 RailCorp Standards

Key RailCorp Standards:

Several significant sets of requirements applicable to 11kV AC Indoor, supervisory controlled switchgear are common to other classes of equipment and are set out in the following RailCorp standards. The equipment shall comply with the relevant requirements set out therein.

Standard Title

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



Standard Title

EP 00 00 00 15 SP Common Requirements for Electric Power Equipment

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

EP 21 00 00 01 SP Insulation Coordination and Surge Arrester Selection

EP 90 10 00 02 SP Standard Voltage Tolerances

Table 3 – Railcorp Standards



3 Definitions, Terms and Abbreviated Terms

3.1 Definitions and Terms

For the purpose of this specification, the terms, definitions and abbreviated terms in AS 1852.441 and the following apply:

Item Meaning

Circuit-breaker A mechanical switching device that is capable of making, carrying and breaking currents under normal circuit conditions, and also of making, carrying for a specified time and breaking currents under specified abnormal conditions, such as those of a short-circuit.

Circuit-breaker panel A switchgear panel complete with a fixed circuit-breaker, switch-disconnector, earthing switch and protection & control equipment.

Earthing switch As defined in (AS 1852(441) 441-14-11).

Fixed circuit breaker A circuit breaker which is not a withdrawable part of the panel assembly in which it is mounted.

Metal-clad switchgear Metal-enclosed switchgear in which certain components, for example, circuit breakers, are arranged in separate compartments that have metal partitions and that are intended to be earthed.

Non-withdrawable switchgear

Switchgear such as circuit-breaker and switches, which are not a withdrawable part of the panel assembly in which they are mounted.

Rated insulation level The combinations of the rated lightning impulse withstand voltage and the rated short duration power frequency withstand voltage specified in AS 2650.

Rated normal current For main circuits and switching devices, the r.m.s. value of the current that they are designed to carry continuously under the specified conditions of use and behaviour.

Rated peak withstand current

For main and earthing circuits, the peak current associated with the first major loop of the short-time withstand current that a mechanical switching device is designed to carry in the closed position under prescribed conditions of use and behaviour.

Rated short-time withstand current

For main and earthing circuits, the r.m.s. value of current that the switching device is designed to carry in the closed position during a specified short time under prescribed conditions of use and behaviour.



Rated voltage The highest r.m.s. phase-to-phase voltage of the supply on which the switchgear is designed to operate.

Switch

A mechanical switching device that is capable of making, carrying and breaking currents under normal circuit conditions, which can include specified operating overload conditions, and also capable of carrying for a specified time, currents under specified abnormal circuit conditions such as those of a short-circuit.

Switchboard Two or more switchgear panels coupled together in various combinations.

Switch-disconnector As defined in (AS 1852(441) 441-14-12).

Switchgear A general term that covers switching devices and their combination with associated control, measuring, indicating, alarm, protective and regulating equipment, also assemblies of such devices and equipment with associated interconnections, accessories, enclosures and supporting structures, intended, in principle, for use in connection with the generation, transmission, distribution and conversion of electric energy.

Withdrawable As defined in (AS 1852(441) 441-13-09).

Table 4 – Definitions and Terms

3.2 Abbreviated terms:

Item Meaning

ACCB Alternating current circuit breaker

Auxiliary Supply Supply for the operation of electronic protection relays, energisation of multi-trip relay coils, energisation of HV ACCB trip and close coils, motor charge and general control circuit operations. Nominally 125V DC or 48V DC.

CT(s) Current Transformer(s)

DC Direct Current

FAT Factory acceptance test

IT Inter-trip



Item Meaning

Low Voltage Compartment

The compartment on the switcgboard 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.

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

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

Railcorp Rail Corporation NSW

RTU Remote Terminal Unit (Interface to SCADA system)

System 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 distribution substations that use HV fuses for protection.

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.

VT Voltage transformer

Table 5 – Abbreviated Terms



4 Revision History

4.1 Version 1.0

• Draft release for one off procurement

4.2 Version 2.0

• First release



5 Background

RailCorp operates a high voltage AC network in which the nominal voltages used are 11kV, 33kV, 66kV and 132kV. RailCorp also operates a 1500V DC network that supplies power for electric traction. The RailCorp high voltage distribution system operates at 11kV and supplies railway signalling, stations and other loads along the rail corridor.

The RailCorp 11kV system comprises both overhead lines and underground cable. Some portions of the RailCorp 11kV system are solidly earthed while other portions are resistively earthed.

System substations are either outdoor or indoor. Indoor arrangements are preferred for new construction. System substations by definition are locations that include a SCADA controlled HV circuit breaker.

Distribution substations are either pole mounted, kiosks (pad mount), or indoor and are generally protected by a HV fuse. Some distribution substations have self-powered HV circuit breakers.



6 Functional Characteristics

The 11kV indoor switchgear covered by this standard shall:

• Provide an 11kV busbar and busbar voltage transformer.

• Provide for connection of 11kV feeders, bus tie cables, system transformer, and distribution transformer circuits to the 11kV busbar.

• Provide for isolation and earthing of feeders, bus tie cables, system transformer, and distribution transformer circuits.

• Provide protection and SCADA control for 11kV feeders, system transformer, and distribution transformer circuits and sections on the 11kV busbar.

• Provide for connection, protection and SCADA control of 11kV harmonic filter or capacitor banks.

• Provide the means to perform a DC cable test on the HV cables, without disturbing existing HV cable connections.

• Provide for a dc control voltage of either: 125 V dc or 48 V dc.



7 Performance Characteristics

7.1 General

The switchboard shall be designed and manufactured in accordance with following standards:

Designation Standard Class

Switchgear (Common specification) Metal enclosed switchgear

AS 2650 AS 62271.200

PM

Internal arc classification (IAC) AS 62271.200 AFLR

Earthing switch AS 62271.102 E2

Disconnector AS 62271.102 M2

Switch AS 60265 - 1 M1, E3

Circuit breaker (except capacitor) Capacitor switching

AS 62271.100 AS 62271.100

M2, E2, C1 M2, E2, C2

Switchgear status indicators (definite indication of position)

AS 62271.102 appendix A

Current transformer AS 1675

Voltage transformer AS 1243

Degrees of protection provided by enclosure (IP code)

AS 60529

General AS 2067

Table 6 – Switchboard standards

The service conditions are to be in accordance with the indoor standard requirements of AS 2650-2005 clause 2.1. Special ambient conditions -5ºC to 50ºC may apply.

Due to possible high ambient temperature when the 11kV switchboard is installed inside a traction substation, derating of the switchboard may apply. RailCorp standard: EP 00 00 00 13 SP, Electrical Power Equipment - Design Ranges of Ambient Conditions provides this detail. Derating factors for high ambient temperature shall be provided in Appendix A, technical schedule tenderer supplied information.

Similar components of all equipment shall fit properly and perform correctly if interchanged.

The configuration and rating requirements are as follows:



Parameter Rating

Number of Phases 3

Rated System Voltage (Ur) Not less than 12kV

Neutral earthing of the system Both: Resistive (NER) and solid earth

Switchboard Metal Clad

Main device type non withdrawable (stationary)

Class Indoor

Busbar Single

Possible extension to switchboard Both sides

Insulation medium SF6 (preferred), cast resin or air

SF6 insulated systems :

All active HV parts are located in hermetically enclosed, gas filled compartments. The gas insulated busbar system is to be continuosly monitored, along with all other HV parts to ensure the integrity of the insulation. Gas filled compartments are to be designed as a sealed pressure system for a minimum 30 year life (clause 5.15.3) in accordance with AS 2650 – 2005. Gas compartments must be welded and all static bushings must be sealed by pressure gaskets for operational life. The operational leak rate for gas insulation must not exceed 0.1% per year.

Rated frequency (fr) 50hZ

Rated lightning impulse withstand voltage (Up) Common value Across the isolating distance

95 kV (peak) 110 kV (peak)

Rated short-duration power-frequency withstand voltage (Ud) Common value Across the isolating distance

28 kV (rms) 32 kV (rms)



Parameter Rating

Rated short time withstand current (Ik) (for main and earthing circuits)

16 kA (rms)

Rated peak withstand current (Ip) (for main and earthing circuits)

40 kA (peak)

Rated duration of short circuit (tk) (for main and earthing circuits)

3 sec

Interruption medium Vacuum (preferred) or SF6.

Internal Arc Classification (IAC) Arc test current Arc test current duration

AFLR 16kA 1 s

Rated supply voltage of closing and opening devices and of auxiliary and control circuits (Ua)

125 V dc (96 – 135 V)

48 V dc (43 – 58 V)

Partition class (as defined in AS 62271 – 200, Annex A) PM

Partial discharge level of complete switchboard including all componenets

< 50 pC

Table 7 –Switchboard common ratings

7.2 Busbar

Most switchboards will require a 630 Amp busbar. The current rating will be specified on the approved for purchase operating diagram to be supplied at time of order. See Appendix B.3

Rating Parameter

Option 1 Option 2

Rated normal current (Ir) 630 Amp 1250 Amp

Table 8 – Busbar characteristics

Components to be fitted:

• Bus bar VT

• Voltmeter and selector switch



• Continuous gas monitoring system (GIS)

• Bus protection equipment (if arc fault activated scheme)

• Other components as necessary

7.2.1 High impedance bus zone protection

Where specified, a high impedance, unit protection scheme: protection relay, MTM, test block etc are to be located within one of the end panels that will be nominated at time of order.

7.2.2 Internal arc fault detection scheme

An alternative to the traditional high impedance scheme is subject to RailCorp approval. If approved, this system is the preferred scheme. If offered as an alternative to the high impedance scheme complete system description is to be provided at tender for assessment.

7.3 Bus tie cable circuit breaker

Railcorp switchgear code = T

Where required for 11kV network reasons more than one switchboard may be required in a substation. Such switchboards would normally be physically separated to reduce the risk of one event damaging both. Switchboards are interconnected by a tie cable through a bus tie circuit breaker at each end of the tie cable.

This is the preferred bus sectioning arrangement at a substation location. The cable tie requires a high impedance unit protection scheme.

All bus cable tie ACCB’s shall be arranged for local and remote control as specified in this document.

In conjunction with the switchboard common standards and ratings specified in clause 7.1, the following additional requirements are specific to bus tie cable ACCB’s

Rating Parameter

Option 1 Option 2



125 V dc 48 V dc

Interrupter type Vacuum preferred or SF6



Number of trip coils 2 independently operated coils

Number of close coils 1

Breaking time 40 msec (max)

Command response time both ON and OFF 25 msec (max)

Rated switch sequence O - 0.3s-CO-3min-CO

Cables connected Bottom front and optional top

Table 9 – Bus tie cable circuit breaker characteristics


• Protection CT, resistors, supply fuses and relays: MCAG34, MTM (see note 1)

• Protection relay test blocks: AREVA MMLG01 (see note 1)

• Trip circuit supervision relays: RMS 1TM10 (1 for each trip coil)

• Remote control for the circuit breaker, with changeover switch for remote control L/R, anti pumping circuitry

• ACCB control circuitry and supply fuses

• Motor operated drive mechanism and controls

• VT secondary protection circuit breakers

• CT test links, wiring terminals

• Cable test facility

• Voltage detection system

• Facilities for padlocking

• Non-resettable mechanical operation counter


Note 1: Only one set of protection equipment is required per bus tie. The protection equipment shall be located together in the appropriate compartment of the circuit breaker at one end only of the tie cable. Normally this will be the lower numbered busbar end.

See clause 8.2 for typical bus tie cable examples.



7.4 Bus coupling circuit breaker

Railcorp switchgear code = B

Where space or building constraints (cable ducts etc) exist a bus coupling circuit breaker arrangement maybe required for the busbar sectionalising function – this is not a preferred configuration.

The switchboard configuration is specified with a bus coupling circuit breaker sectioning the busbar within a switchboard.

Rating Parameter

Option 1 Option 2



125 V dc 48 V dc

Rated short time withstand current (Ik) 16 kA (allows fault on outgoing part of the board)







Table 10 – Bus coupling circuit breaker characteristics


• Protection CT, resistors, supply fuses and relays: MCAG34, MTM

• Protection relay test blocks: AREVA MMLG01

• Trip circuit supervision relays: RMS 1TM10 (1 for each trip coil)

• Remote control for the circuit breaker, with changeover switch for remote control L/R, anti pumping circuitry,












7.5 Feeder Circuit Breaker

Railcorp switchgear code = F

All feeder ACCB’s are to be arranged for local and remote control as specified in this document.

In conjunction with the switchboard common standards and ratings specified in clause 7.1, the following additional requirements are specific to feeder ACCB’s

Rating Parameter

Option 1 Option 2


125 V dc 48 V dc

Rated normal current (Ir) 400 Amp








Table 11 – Feeder circuit breaker specific requirements




• Protection CT, supply fuses and relays: MiCOM P127, MiCOM P521(if PW required)

• Protection relay test blocks: AREVA MMLG01(1 per protection relay)


• ACCB control circuitry and protection relay supply fuses






• Moving coil ammeter in phase L2

• Transducer, current in phase L2




7.6 System transformer (incomer) circuit breaker

Railcorp switchgear code = ST

All incomer ACCB’s are to be arranged for local and remote control as specified in this document.

In conjunction with the switchboard common standards and ratings specified in clause 7.1, the following additional requirements are specific to incomer ACCB’s

Rating Parameter

Option 1 Option 2


125 V dc 48 V dc











Table 12 – System transformer circuit breaker specific requirements


• Protection CT, supply fuses and relays: MiCOM P127

• Neutral leakage relay: MiCOM P127 (if required)


• Trip circuit supervision relays: RMS 1TM10



• VT on incomer side


• CT for transformer differential scheme







• Transducer, voltage B phase






7.7 Distribution transformer (outgoing) circuit breaker

Railcorp switchgear code = t

All Distribution transformer ACCB’s are to be arranged for local and remote control as specified in this document.

In conjunction with the switchboard common standards and ratings specified in clause 7.1, the following additional requirements are specific to Distribution transformer ACCB’s

Rating Parameter

Option 1 Option 2


125 V dc 48 V dc









Table 13 – Distribution tx circuit breaker specific requirements


• Protection CT, supply fuses and relays: MiCOM P127 or MiCOM P632, MTM, MTA













• Transducer, voltage (if VT fitted to circuit side)




7.8 Capacitor / harmonic filter circuit breaker

Railcorp switchgear code = C

A capacitor bank or harmonic filter circuit breaker will generally be similar to a feeder circuit breaker, however in each instance of use the circuit breaker opening and closing duty must be approved by the manufacturer.

A capacitor circuit breaker shall have the ratings of a feeder circuit breaker, however it will be confirmed with the manufacturer as being capable of breaking capacitive load current and subsequently maintain a resulting voltage across its contacts as defined below:

All capacitor ACCB’s are to be arranged for local and remote control as specified in this document.

In conjunction with the switchboard common standards and ratings specified in clause 7.1, the following additional requirements are specific to capacitor ACCB’s

Rating Parameter

Option 1 Option 2


125 V dc 48 V dc







Rated short-duration withstand voltage (across the isolating distance) (Ud)

12 kV AC rms with 13.5kV DC offset



Table 14 – Capacitor circuit breaker specific requirements


• Protection relay: MiCOM P127

• Protection relay test block: AREVA MMLG01

• Trip circuit supervision relay: RMS 1TM10


• ACCB control circuitry and protection relay supply fuses








• Additional components as required






Prior Service Conditioning

Circuit breaker contacts for capacitor or filter control shall be conditioned prior to use in switching a capacitor bank. This may be achieved by placing a low voltage welder across the circuit breaker contacts, ramping the current to the circuit breaker rating then successively opening and closing the breaker. Conditioning removes any manufacturing sharp edges that may have resulted which in first true service may ultimately lead to re-strike.

An alternate method of achieving conditioned capacitor bank circuit breaker contacts is to swap the circuit breaker with one that is already in service and that has been switched on load. The circuit breaker to be swapped must be similar in all other respects to the new unconditioned circuit breaker.

Confirmation of Opening Duty

A circuit breaker intended to supply a capacitor bank shall be confirmed suitable for the duty by the manufacturer, such that no re-strike will occur after the arc is extinguished in each pole.

It shall be noted that capacitor bank de-energisation will place a DC offset on the power frequency voltage across the circuit breaker contacts. In the worst case this DC offset may be taken to be 150% of the system peak phase to neutral voltage.

If a circuit breaker is not able to be confirmed by the manufacturer as suitable for capacitor bank opening resulting in a 150% DC voltage on the load side, then the expected opening transients shall be simulated and supplied to the manufacturer for consideration and approval.

Where a floating neutral capacitor bank is used, then opening transient voltage simulations shall take into account possible purely capacitive coupling of the capacitor bank neutral to earth and possible purely resistive coupling of the capacitor bank neutral to earth. Either case results in a differing trapped charge on the capacitor bank neutral following the last two poles of the circuit breaker to open.

Time domain simulations shall account for saturable Voltage Transformers if they exist on the capacitor bank load side of the circuit breaker.

Time domain simulations shall account for individual pole opening on current zero crossings when an open command is issued.

Vacuum interrupting is preferred due to it’s natural dielectric recovery upon arc extinguishing. If SF6 interrupters are used then the SF6 arc quenching mechanism shall not rely on movement of the SF6 gas through the arc to quench the arc. This requirement allows for unexpected delayed re-strike to be interrupted with arc quenching and dielectric strength recovery with the circuit breaker contacts held still in the fully open position.

Confirmation of Closing Duty



The designed capacitor bank inrush currents and contact voltages on Closing shall be time domain simulated. Three phase plots of the circuit breaker contact inrush current shall be forwarded to the circuit breaker manufacturer for approval.

Time domain simulations shall account for any back to back capacitor bank switching where applicable.

Circuit earthing

Provision of suitable earthing switches, interlocks and components for circuit and capacitor discharge capability shall be included. Where required, supplementary earthing switch(s), interlocks and circuity for the neutral of a floating capacitor bank shall be provided.

7.9 Feeder circuit breaker (Non Auto)

Railcorp switchgear code = Fna

Supervisory controlled circuit breaker configured as non-auto (no CT’s or protection relay fitted).

Rating Parameter

Option 1 Option 2


125 V dc 48 V dc









Table 15 – Feeder non auto circuit breaker specific requirements




• Remote control for the circuit breaker, with changeover switch for local/remote control L/R, anti pumping circuitry.



• Auxiliary contacts






7.10 Feeder network switch (Supervisory Indication only)

Railcorp switchgear code = D

Fully rated load break, fault make feeder network switch complete with integral fully rated earth switch configured for supervisory indication only.

Parameter Rating

Feeder Fault make, load break switch to AS 60265.1 class E2/M1 – Rated current 400 Amp

Table 16 – Feeder switch specific requirements


• Auxiliary contacts








8 Technical Characteristics

8.1 General

The switchboards and switchgear shall be provided in accordance with the performance requirements specified in chapter 7 and the technical requirements of this chapter.

8.2 Switchboard Configurations

Due to the variability of the requirements for SCADA controlled 11kV switchboards, it is not possible to identify all configurations. Each switchboard is to be designed and manufactured specifically for each site within the following constraints:

• The switchgear functional units shall be assembled into switchboard panels.

• Each switchboard shall include a bus bar voltage transformer (VT).

• Standard circuit breaker functions are: Feeder, System Transformer, Distribution Transformer, Tie (Bus) and Bus coupler.

• Switchboards with single bus tie panels should have the bus tie at one end of the switchboard. Switchboards with two bus tie panels should have the bus tie panels at opposite ends of the switchboard. The position of each functional unit will be specified at time of order in accordance with the approved for purchase operating diagram – see Appendix B.3

8.2.1 Supply Point switchboard configurations

Application Code Build

Supply Point ST1FT 1 incoming System Tx ACCB with VT + 1 Feeder ACCB +1 Tie ACCB + Busbar VT

Supply Point ST2F 1 incoming System Tx ACCB with VT + 2 Feeder ACCB + Busbar VT

Supply Point ST2FC 1 incoming System Tx ACCB with VT + 2 Feeder ACCB + 1 Capacitor ACCB + Busbar VT

Supply Point ST2FtT 1 incoming System Tx ACCB with VT + 2 Feeder ACCB + 1 Distribution tx ACCB + 1 Tie ACCB + Busbar VT

Supply Point ST3F 1 incoming System Tx ACCB with VT + 3 Feeder



ACCB + Busbar VT

Supply Point ST4F 1 incoming System Tx ACCB with VT + 4 Feeder ACCB + Busbar VT

Table 17 – Supply point switchboard configuration

8.2.2 Switching Station switchboard configurations


Switching Station

2FT 2 Feeder ACCB + 1 Tie ACCB + Busbar VT

Switching Station

3F 3 Feeder ACCB + Busbar VT

Switching Station

3FT 3 Feeder ACCB + 1 Tie ACCB + Busbar VT

Switching Station

4F 4 Feeder ACCB + Busbar VT

Table 18 – Switching Station switchboard configuration

8.2.3 System substation switchboard configurations


System Substation

1Ft 1 Feeder ACCB + 1 Distribution tx ACCB + Busbar VT

System Substation

1FtT 1 Feeder ACCB + 1 Distribution tx ACCB + 1 Tie ACCB + Busbar VT

System Substation


System Substation


Table 19 – System Substation switchboard configuration



8.2.4 Mid point switching switchboard configuration


Mid point switching

1FnaD 1 Feeder ACCB (non auto) + 1 network Switch (D) (supy indication)+ Busbar VT

Mid point switching

1FD 1 Feeder ACCB + 1 network Switch (D) (supy indication)+ Busbar VT

Table 20 – Feeder mid point switchboard configuration

8.2.5 Bus coupled circuit breaker switchboard


Bus coupled by ACCB

ST2FB1Ft 1 incoming System Tx ACCB with VT + 2 Feeder ACCB +. Busbar VT +. Bus coupling ACCB + 1 Feeder ACCB + 1 Distribution tx ACCB + Busbar VT

Table 21 – Bus coupled switchboard configuration

8.2.6 Example switchboard configurations

Figure 1 – Example Switchboard type ST1FT and 3FT



Figure 2 – Example Switchboard type 2FtT

Figure 3 – Type ST1FT

11KV SWITCHBOARDCONFIGURATION ST1FT

13/6/2007

CT & RELAY DETAILSC1: 600/1 0.03PL120R2.0C2: 300/150/1 10P50F20C3: 300/1 0.05PL50R1.0C4: 450/ 1 10P50F20C5: 450/0.577 0.02PL100R3.0 (based on 6.25MVA tx)

Current transducer TC1: ACCB TRIP COIL 1TC2: ACCB TRIP COIL 2

87/L: AREVA MiCOM P52151/L, 67/L: AREVA MiCOM P12787/B, 87/BT: AREVA MCAG34

C3

C2

MTM

TRIPS (all TC2):33/11KV Tx ACCB (both ACCB's)FEEDER ACCBTIE ACCBTIE ACCB (ADJACENT SWITCHBOARD)

87/L

TC1

BREAKER FAIL

67/L

FEEDERACCB

TIEACCB

C1

C187/BT

C1

C1

33/11KV TxACCB

TC2

TC2

TC1

BREAKER FAIL

VT

VT

87/B

FROM33KV PANEL

TC1

FROM ADJACENTTIE ACCB

11kV BUSBAR

C4ImA51/L

C5TO 33KV PANEL

ImA



Figure 4 – Type ST2F

C3

C2

MTM

TRIPS (all TC2):33/11KV Tx ACCB (both ACCB's)FEEDER 1 ACCBFEEDER 2 ACCB

ImA

87/L

TC1

BREAKER FAIL

67/L

FEEDER 1ACCB

FEEDER 2ACCB

C1 C1

C1

C5TO 33KV PANEL

C4ImA51/L

TC2

TC2

TC1

BREAKER FAIL

VT

VT

87/B

11KV SWITCHBOARDCONFIGURATION ST2F

FROM33KV PANEL

C3

C2ImA

87/L

TC1

67/L

TC2

INTE

RTR

IP IN

ITIA

TE

11kV BUSBAR

13/6/2007



87/L: AREVA MiCOM P52151/L, 67/L: AREVA MiCOM P12787/B: AREVA MCAG34



Figure 5 – Type ST1FtT

C3

C2

MTM

TRIPS (all TC2):33/11KV Tx ACCB (both ACCB's)FEEDER ACCBDISTRIBUTION Tx ACCBTIE ACCBTIE ACCB (ADJACENT SWITCHBOARD)

ImA

87/L

TC1

BREAKER FAIL

67/L

FEEDERACCB

TIEACCB

C1

C187/BT

C1

C1

C5TO 33KV PANEL

C4ImA51/L

33/11KV TxACCB

TC2

TC2

TC1

BREAKER FAIL

VT

87/B

11KV SWITCHBOARDCONFIGURATION ST1FtT

FROM33KV PANEL

TC1


VT

DISTRIBUTION TxACCB

C1

11kV BUSBAR

51

MTM

87/T C6

C7ImA

TC1

MTA

BUCHHOLZ

TC2

O/C

E/F

TO 415VACCB

CT & RELAY DETAILSC1: 600/1 0.03PL120R2.0C2: 300/150/1 10P50F20C3: 300/1 0.05PL50R1.0C4: 450/ 1 10P50F20C5: 450/0.577 0.02PL100R3.0 (based on 6.25MVA tx)C6: 100/1 0.15PL50R0.3C7: 100/1 10P50F20


87/L: AREVA MiCOM P52151/L, 67/L: AREVA MiCOM P12787/B, 87/BT: AREVA MCAG3487/T: AREVA MiCOM P632

ImA

13/6/2007




C3

C2

MTM

TRIPS (all TC2):33/11KV Tx ACCB (both ACCB's)FEEDER 1 ACCBFEEDER 2 ACCBFEEDER 3 ACCB

ImA

87/L

TC1

BREAKER FAIL

67/L

FEEDER 2ACCB

FEEDER 3ACCB

C1 C1

C1

C5TO 33KV PANEL

C4ImA51/L

33/11KV TxACCB

TC2

TC2

TC1

BREAKER FAIL

VT

VT

87/B


FROM33KV PANEL

C3

C2ImA

87/L

TC1

67/L

TC2

INTE

RTR

IP IN

ITIA

TE

11kV BUSBAR

13/6/2007

C3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2







C3

C2

MTM

TRIPS (all TC2):33/11KV Tx ACCB (both ACCB's)FEEDER 1 ACCBFEEDER 2 ACCBFEEDER 3 ACCBFEEDER 4 ACCB

ImA

87/L

TC1

BREAKER FAIL

67/L

FEEDER 2ACCB

FEEDER 3ACCB

C1 C1

C1

C5TO 33KV PANEL

C4ImA51/L

33/11KV TxACCB

TC2

TC2

TC1

BREAKER FAIL

VT

87/B


FROM33KV PANEL

C3

C2ImA

87/L

TC1

67/L

TC2

INTE

RTR

IP IN

ITIA

TE

11kV BUSBAR

13/6/2007

C3

C2ImA

87/L

TC1

67/L

FEEDER 4ACCB

C1

TC2

VTC3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2




ImA



Figure 8 – Type 2FT

C3

C2

MTM

TRIPS (all TC2):FEEDER 1 ACCBFEEDER 2 ACCBTIE ACCBTIE ACCB (ADJACENT SWITCHBOARD)

ImA

87/L

TC1

INTE

RTR

IP IN

ITIA

TE

67/L

FEEDER 2ACCB

TIEACCB

C1

C187/BT

C1

TC2

BREAKER FAIL

87/B

TC1


VTC3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2

11kV BUSBAR

MTACT & RELAY DETAILSC1: 600/1 0.03PL120R2.0C2: 300/150/1 10P50F20C3: 300/1 0.05PL50R1.0

Current transducer

TC1: ACCB TRIP COIL 1TC2: ACCB TRIP COIL 2

87/L: AREVA MiCOM P52151/L, 67/L: AREVA MiCOM P12787/B,87/BT: AREVA MCAG34

ImA



Figure 9 – Type 3F

C3

C2

MTM

TRIPS (all TC2):FEEDER 1 ACCBFEEDER 2 ACCBFEEDER 3 ACCB

ImA

87/L

TC1

67/L

FEEDER 2ACCB

FEEDER 3ACCB

C1 C1

TC2

BREAKER FAIL

87/B

VTC3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2

C3

C2ImA

87/L

TC1

67/L

TC2

INTE

RTR

IP IN

ITIA

TE

11kV BUSBAR

CT & RELAY DETAILSC1: 600/1 0.03PL120R2.0C2: 300/150/1 10P50F20C3: 300/1 0.05PL50R1.0

Current transducer



ImA



Figure 10 – Type 3FT

C3

C2

MTM

TRIPS (all TC2):FEEDER 1 ACCBFEEDER 2 ACCBFEEDER 3 ACCBTIE ACCBTIE ACCB (ADJACENT SWITCHBOARD)

ImA

87/L

TC1

BREAKER FAIL

INTE

RT R

IP IN

ITIA

TE

67/L

FEEDER 3ACCB

TIEACCB

C1

C187/BT

C1

C1

C2ImA51/L

FEEDER 2ACCB

TC2

TC2TC1

BREAKER FAIL

87/B

11KV SWITCHBOARDCONFIGURATION 3FT

TC1


VTC3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2

C387/L

INTERTRIP INITIATE

11kV BUSBAR


Current transducer



ImA




C3

C2

MTM

TRIPS (all TC2):33/11KV Tx ACCBFEEDER 1 ACCBFEEDER 2 ACCBFEEDER 3 ACCBFEEDER 4 ACCB

ImA

87/L

TC1

BREAKER FAIL

67/L

FEEDER 2ACCB

FEEDER 3ACCB

C1 C1

C1

C5TO 33KV PANEL

C4ImA51/L

33/11KV TxACCB

TC2

TC2

TC1

BREAKER FAIL

VT

87/B

11KV SWITCHBOARDCONFIGURATION 4F

FROM33KV PANEL

C3

C2ImA

87/L

TC1

67/L

TC2

INTE

RTR

IP IN

ITIA

TE

11kV BUSBAR

13/6/2007

C3

C2ImA

87/L

TC1

67/L

FEEDER 4ACCB

C1

TC2

VTC3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2




ImA



Figure 12 – Type 1Ft

C3

C2

MTM

TRIPS (all TC2):FEEDER ACCBDISTRIBUTION Tx ACCB

ImA

87/L

TC1

67/L

FEEDERACCB

C1

TC2

BREAKER FAIL

VT

87/B

DISTRIBUTION TxACCB

INTE

RTR

IP IN

ITIA

TE

11kV BUSBAR

C1

51

MTM

87/T C4

C5ImA

TC1

MTA

BUCHHOLZ

TC2

O/C

E/F

TO 415VACCB

CT & RELAY DETAILSC1: 600/1 0.03PL120R2.0C2: 300/150/1 10P50F20C3: 300/1 0.05PL50R1.0C4: 100/1 0.15PL50R0.3C5: 100/1 10P50F20

Current transducer


87/L: AREVA MiCOM P52151, 67/L: AREVA MiCOM P12787/B: AREVA MCAG3487/T: AREVA MiCOM P632

ImA



Figure 13 – Type 1FtT


TRIPS (all TC2):FEEDER 1 ACCBFEEDER 2 ACCBDISTRIBUTION Tx ACCBTIE ACCBTIE ACCB (ADJACENT SWITCHBOARD)



87/L: AREVA MiCOM P52151, 67/L: AREVA MiCOM P12787/B, 87/BT: AREVA MCAG3487/T: AREVA MiCOM P632

C3

C2

MTM

ImA

87/L

TC1

67/L

FEEDER 2ACCB

TIEACCB

C1

C187/BT

C1

TC2

BREAKER FAIL

87/B

11KV SWITCHBOARDCONFIGURATION 2FtT

TC1


VT

DISTRIBUTION TxACCB

C1

11kV BUSBAR

51

MTM

87/T C4

C5ImA

TC1

MTA

BUCHHOLZ

TC2

O/C

E/F

TO 415VACCB

ImA

C3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2

C3

C2

MTM

TRIPS (all TC2):FEEDER ACCBDISTRIBUTION Tx ACCBTIE ACCBTIE ACCB (ADJACENT SWITCHBOARD)

ImA

87/L

TC1

67/L

FEEDERACCB

TIEACCB

C1

C187/BT

C1

TC2

BREAKER FAIL

87/B


TC1


VT

DISTRIBUTION TxACCB

C1

11kV BUSBAR

51

MTM

87/T C4

C5ImA

TC1

MTA

BUCHHOLZ

TC2

O/C

E/F

TO 415VACCB

13/6/2007


Current transducer



ImA




(Note 2nd feeder shown on top of busbar. This is diagrammatic only – it is not an incomer but shown here to fit across the page)

C3

C2

MTM

TRIPS (all TC2):FEEDER 1 ACCBFEEDER 2 ACCBFEEDER 3 ACCBDISTRIBUTION Tx ACCBTIE ACCBTIE ACCB (ADJACENT SWITCHBOARD)

ImA

87/L

TC1

BREAKER FAIL

INTE

RTR

IP IN

ITIA

TE

67/L

FEEDER 3ACCB

TIEACCB

C1

C187/BT

C1

C1

C2ImA51/L

FEEDER 2ACCB

TC2

TC2TC1

BREAKER FAIL

87/B


TC1


VTC3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2

C387/L

DISTRIBUTION TxACCB

INTERTRIP INITIATE

11kV BUSBAR

C1

51

MTM

87/T C4

C5ImA

TC1

MTA

BUCHHOLZ

TC2

O/C

E/F

TO 415VACCB

13/6/2007


Current transducer



ImA



Figure 16 – Type 1FnaD

FEEDER ACCB

NETWORK LOADDISCONNECTOR & EARTHSWITCH

(SCADA INDICATION ONLY)

VT

11kV BUSBAR

C3

C2ImA

87/L

TC1

67/L

C1

TC2

TRIPS (all TC2):FEEDER ACCB

87/B

INTE

RTR

IP IN

ITIA

TE

C1

MTM


Current transducer


87/L: AREVA MiCOM P52167/L: AREVA MiCOM P127

ImA

Note:1. The requirement for busbar protection will be specified at time of order.

Figure 17 – Type 1FD

FEEDER(NON AUTO)

ACCB

NETWORK LOADDISCONNECTOR & EARTHSWITCH

(SCADA INDICATION ONLY)

VT

11kV BUSBAR



The switch shown in Figure 17 – Type 1FD includes a CT for a busbar protection scheme. The need for a busbar scheme will be specified at time of order. If the busbar scheme is not required the switch will not require a CT.

Figure 18 – Type ST1FB1Ft

8.3 Rated Insulation Level

All switchgear shall have the same Rated Peak Lightning Impulse Withstand Voltage.

8.4 Control Voltage – DC auxiliary supply voltage

The auxiliary supply voltage shall be either 125 V dc or 48 V dc (nominal).

Switchboards are to be suitable for either voltage. The specific voltage will be nominated at time of order (see Appendix B.3Error! Reference source not found.).

Auxiliary supply voltage requirements are specified in EP 00 00 00 15 SP, Common Requirements for Electric Power Equipment.

MTM

TRIPS (all TC2):FEEDER 2 ACCBDISTRIBUTION Tx ACCBBUS-SECTION ACCB

INTE

RTR

IP IN

ITIA

TE

87/B2

11KV SWITCHBOARDCONFIGURATION S1FB1Ft


C3

C2ImA

87/L

TC1

67/L

FEEDER 2ACCB

C1

TC2

SECTION 2

13/6/2007

MTM

TRIPS (all TC2):33/11KV Tx ACCB (both ACCB's)FEEDER 1 ACCBBUS-SECTION ACCB

BREAKER FAIL

C1

C1

C5TO 33KV PANEL

C4ImA51/L

33/11KV TxACCB

TC2

TC1

BREAKER FAIL

VT

VT

87/B1

FROM33KV PANEL

SECTION 1

13/6/2007

C3

C2ImA

87/L

TC1

67/L

FEEDER 1ACCB

C1

TC2

C1

BREAKER FAIL

DISTRIBUTION TxACCB

C1

51

MTM

87/T C6

C7ImA

TC1

MTA

BUCHHOLZ

TC2

O/C

E/F

TO 415VACCB



87/L: AREVA MiCOM P52151/L, 67/L: AREVA MiCOM P12787/B1, 87/B2: AREVA MCAG34

ImA



8.5 Busbar

All joints and tees in busbars and busbar connections shall be made with an approved connection type.

If bolts, nuts and washers are used they shall be suitably protected against corrosion in accordance with ISO 9227.

If any part of the busbar is air insulated or requires routine service then bus bar earthing facilities shall be provided.

8.6 Gas insulation (where applicable)

Sulphur-hexafluoride (SF6) insulated switchgear shall be filled with SF6 that complies with the requirements of IEC 60376. Cladded gas compartments shall be designed as hermetically sealed pressure system according to AS 62271-200.

The switchgear shall be factory sealed so as not require any routine gas replenishment during installation or in normal service.

The complete busbar system shall be integrated completely and throughout within the gas filled cladded compartments of the switchgear. All HV conducting parts are to be isolated from the external environment.

The design, construction and sealing of gas compartments shall be such that the gas will not require replenishment for at least 30 years.

Gas compartment seals of static bushings and pressure relief devices shall be kept to a minimum. A common gas tight rotary bushing shall be used for any rotary actuators.

Gas compartments are to be welded and static bushings must be sealed by pressure gaskets for operational life. The operational leak rate for gas insulation must not exceed 0.1% per year.

Bushings are to be used between the internal gas filled clad compartment and the external atmosphere for cable connections and for the flanging of metal enclosed components (VT’s etc).

It is preferred that switchgear that requires gassing after panels are assembled into switchboards be gassed at the factory and transported to site as a single unit.

Only if specifically approved by RailCorp, shall gas compartments be assembled, gassed and sealed on site. In this situation the supplier shall test the tightness, in accordance with AS 2650 clause 6.1, and shall certify and warrant for gas tightness.

A device for monitoring the SF6 pressure in each gas compartment while in service shall be provided. This device shall provide indication of the minimum



permissible pressure level for safe operation and shall provide two level alarms - level 1 alarm, level 2 alarm. The pressure level monitoring device shall be clearly visible to the operator from the operating side of the switchgear panel. Remote signalling contacts for SCADA connection for alarm conditions are to be provided.

8.6.1 Pressure relief for gas compartments

Pressure relief devices of each gas-filled cladded compartment are to be effected by appropriate relief devices into a pressure relief area. The pressure relief area shall be partitioned against the cable connection compartment using metallic cover.

Direction for pressure relief is, for the cable compartment directed downwards; for other compartments upward to the rear.

8.6.2 On-site installation and possible extension

Individual functional units shall be designed so that they can be lined up on site without undue dismantling of existing equipment or the need to regas. A coupling section is to be available to connect busbars of adjacent modules.

This coupling arrangement shall provide for subsequent extension without requiring interventions into existing modules. This shall be documented conclusively in the equipment manuals.

8.6.3 Current transformers

The switchgear is to be equipped for current measurement of the functional units, with low voltage CT’s which are separately accessible in the cable connection compartment and which must be mounted outside of the gas compartment onto the extended outer cone-type bushing.

Retrofitting or replacement of the CT shall be possible without intervention in the gas compartment from the switchgear side.

8.6.4 Voltage transformers

Metal enclosed, touch safe and grounded inductive voltage transformers should be provided. VT requirements are specified in EP 19 00 00 02 SP.

VT’s on the busbar are to be direct plug-in to the switchgear outside of the gas filled cladded compartment.

VT’s on outgoing (or incoming) circuits are to be located outside of the gas compartment. They can be plug-in directly or connected via a pluggable cable connection.

Direct plug-in VT’s in the outgoing (incoming) circuit is acceptable to Railcorp. Transformer isolation and earthing on the primary side where required shall be provided.



8.6.5 End of life gas recovery

After the operational life of the switchboard it must be possible to recover the complete SF6 gas of every gas filled compartment by a serial recovery valve.

8.7 Earthing bar

To assist with stray current mitigation measures from the dc traction system, it may be necessary to connect 11kV cable screens to a separate cable screen earth bar on feeder panels only. This arrangement is to facilitate future installation of a transient earth clamp. The transient clamp acts as a DC decoupler, to provide DC isolation between earthing points that are still AC connected. Under an AC earth fault the clamp impedance momentarily changes state to a virtual short circuit, acting to provide a direct connection of HV cable screens to the switchboard earth bar. The transient earth clamp blocks the path to dc stray current that could otherwise flow via the cable screen.

Note some HV panels will require all HV earth screens to be directly connected to the switchboard earth bar.

Each switchgear panel shall include two copper earthing bars, rated for maximum fault levels and not less than 120 mm2 cross section area to facilitate earthing.

The cable screen earth bar shall be connected to the switchboard earth bar via removable links and shall be isolated from similar bars in adjacent panels. It shall be insulated from the frame of the switchboard by insulated mounts that have been rated for maximum earth potential rise and tested for at least 11/√3 kV for 1 minute. The cable screen earth bar shall provide for connection of the removable link, three HV cable screens and two cable connections holes for a transient earth clamp.

The switchboard earth bar shall interconnect adjacent switchgear panels and provide:-

• for all switchgear bonding

• for two cable connections to the main substation earth grid

• for a removable link per feeder panel for connection to the insulated earth screen earthing bar

• for three cable screens for panels other than feeders

• requirements for circuit test facility (see clause 8.19)

Earth termination requirements are provided in EP 00 00 00 15 SP, Common Requirements for Electric Power Equipment.



8.8 Current Transformers

The circuit-breaker panels shall be provided with three phase sets of protection current transformers in compliance with EP 19 00 00 02 SP Protection System Requirements for the High Voltage Network.

8.8.1 CT rating plate

A rating plate shall be fitted to each current transformer. A second identical plate is to be fixed within the LV compartment in such a position that facilitates ease of access to read the information.

8.9 Voltage Transformers

8.9.1 General

A three-phase (or three single phase) voltage transformer(s) in compliance with EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network shall be provided for each switchboard.

A voltage transformer is required for each incoming supply transformer ACCB.

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 (see the Technical Schedule at Appendix A ). 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.

8.9.2 Directional Protection Supply Alarm

Within each panel the low voltage side of the voltage transformer supply to protection relays shall be protected by a separate circuit-breaker of adequate breaking capacity complete with voltage free contacts.

The circuit breaker(s) shall have an normally closed voltage free auxiliary contact which is connected to the SCADA system to give an “FEEDER XXX DIRECTIONAL VOLTAGE FAIL' alarm

The main voltage transformer secondary circuit-breaker should discriminate for faults protected by the individual panel circuit breakers.

8.9.3 Voltage Transformer Alarm

A three phase, phase failure relay in compliance with EP 19 00 00 02 SP, Protection System requirements for the High Voltage Network shall be connected to the secondary of the voltage transformer on the load side of the main LV circuit breaker.



8.10 Low voltage cabinet

The secondary equipment for protective relays, controls, measurements, metering and other systems shall be housed in a low voltage cabinet located in or immediately above the relevant circuit breaker panel.

The low voltage panel is to be a lockable, closed, fully shrouded and arc resistant cabinet to IP3X standard with mechanical and electrical interface to accommodate digital protection relays and other secondary equipment for control and measurement. Where appropriate equipment may be mounted on a torsion resistant panel door.

Mechanical drive elements must not be installed in the low voltage cabinet.

8.11 Circuit-Breakers

8.11.1 General

Circuit-breaker panels shall comprise a fixed circuit breaker, switch-disconnector and earthing switch.

Circuit-breakers shall comply with the requirements of AS 2650 and IEC 62271 – 100.

Circuit-breakers, switch-disconnectors and earthing switches that have long mechanical and electrical endurance (as defined in IEC 62271 parts 100 & 102) are preferred.

The secondary equipment for protective relays, controls, measurements, metering and other systems shall be housed in a low voltage cabinet located in or immediately above the relevant circuit breaker panel.

Mechanical drive elements must not be installed in the low voltage cabinet.

Details of the required protection schemes are specified in RailCorp standard EP 19 00 00 02 SP – Protection System requirements for the high voltage network. The switchboard shall incorporate the applicable requirements of EP 19 00 00 02 SP.

8.11.2 Circuit Breaker Type

The interrupting medium shall be either vacuum (preferred) or SF6.

Interrupters must enable at least 10,000 operations at rated current and at least 50 operations at rated short circuit breaking current.

8.11.2.1 Vacuum Circuit-Breakers

The contacts of the interrupter shall be held open by a positive fail-safe device independent of interrupter vacuum. The closing arrangement shall be designed so as to give a positive closing action whilst overcoming the contact hold open device.



8.11.2.2 SF6 Circuit-breakers

Each circuit breaker shall consist of three separate "pole units" mounted on a single piece frame and shall be mechanically interconnected. The design of the interrupting mechanism and contacts shall be such that the energy dissipated in the SF6 gas is low and does not cause appreciable degradation of gas.

Each pole shall be provided with a separate and independent set of main and arcing contacts to minimise degradation of main contacts during fault interruption. The arcing contacts shall be terminated by tungsten or similar tips and shall be of a high electrical endurance. The main contacts shall be capable of carrying the maximum short circuit current without damage. If butt type arcing contacts are provided, it shall be possible to check the wear of arcing contacts without the necessity to open pole units.

The internal surfaces of all porcelains shall not be glazed.

The gas tightness shall not depend on any part likely to wear or age.

Certificates and details of tests for tightness carried out on pole units of breakers shall be maintained.

8.11.3 Circuit-breaker operating mechanisms

The circuit-breaker operating mechanism shall be an integral part of the circuit breaker.

The busbar isolator and associated earth switch is to be actuated mechanically. Auxiliary switches shall provide indication of each switch position. See 8.25.1.

Any part of the circuit breaker mechanism that requires routine inspection and maintenance shall not be enclosed in any gas tight compartment.

Solenoid based mechanisms are not to be used.

All circuit breaker panels shall be the XEM type (stored energy operation by means of energy stored in a motor-charged spring with manual or electrical release).

All circuit breakers in the closed position shall be able to trip-close-trip before the spring needs to be charged again.

8.11.4 Circuit-breaker Operation and Control

The circuit-breaker closing mechanism shall be electrically operated, trip-free. The circuit-breaker mechanism shall provide lockout preventing closing, as specified in Clause 441-14-23 of AS 1852 (441) - 1985

The circuit breakers shall be arranged for operation by local control or by remote supervisory control. The supervisory equipment will provide an open or close command signal of 1.0 A maximum at the nominated DC control voltage continuous for 1.0 second and up to 2 seconds duration.



The circuit breaker shall close without delay when the close command signal is applied. While this command signal is applied, the circuit breaker shall not make a second attempt to close if it fails to close on the first attempt.

The circuit breaker shall open without delay when the open command signal is applied independently to any of the trip coils or to all trip coils simultaneously.

A mechanical push-button or similar device for tripping the circuit breaker shall be provided.

Continuously rated control equipment shall be provided to make the successful closing of the circuit-breaker independent of the length of time that the control switch is held in the CLOSE position and to ensure that only one closing attempt can be made if the control switch is held in the CLOSE position.

8.12 Indication

The circuit-breaker and switch panel shall have indication clearly visible from the front of the panel (i.e. either on the circuit breaker or on the circuit-breaker panel).

The circuit-breaker / switch switchgear panel shall have the following definite indication:

1) Circuit-breaker open/close;

2) Switch disconnector open/close (if applicable);

3) Earth switch position;

4) Stored energy device charged/discharged;

5) Non-resettable mechanical operation counter.

8.13 Auxiliary Equipment

Each switchgear panel shall be fitted with:

1) A control panel with:

a) A local CLOSE and OPEN switch or push-buttons coloured red and green respectively.

b) LOCAL – REMOTE (SUPERVISORY) changeover switch;

c) Capability for installation of instrumentation to measure:

• Voltage

• Current



• Energy

The requirement for which instruments are to be installed will be specified at the time of order.

The requirements of any instrumentation to be fitted, are set out in section 8.23 Instruments, Transducers and Metering

2) Two normally open and two normally closed auxiliary switches rated at 5 amperes in a 125 V d.c. inductive circuit or a 415 V a.c. circuit. (These auxiliary switches shall be provided in addition to those essential to the circuit-breaker operation).

3) A mechanically operated indicator, indelibly marked, to show whether the circuit breaker is open or closed. The word OPEN shall be visible only if the circuit breaker is open and the word CLOSED shall be visible only if the circuit breaker is closed. If colours are used in addition, then the colour green shall indicate the open condition and the colour red shall indicate the closed condition.

4) Electrically operated indicating lights of the LED type.

5) A non-resettable operation counter.

6) A set of terminals for the termination of auxiliary wiring. All auxiliary wiring such as for remote closing and tripping circuits, incoming DC control supplies and all spare auxiliary switches shall be connected to these terminals.

7) Mechanical interlocks shall be provided in compliance with 8.14 and clause 5.11 of AS 62271-200 to prevent unsafe operation, including:

a) Automatic opening of a circuit-breaker when it is used to earth a circuit or the bus bar

b) Closing of an earthing switch unless the circuit-breaker is in the open position

Each switchboard shall be fitted with a voltmeter and associated phase selection switch to indicate the bus voltage.

Anti-condensation heaters where required shall be provided. A current detection circuit using a supervised reed relay shall be incorporated in the heater control scheme.

The requirement for which instruments are to be installed will be specified at the time of order.

8.14 Interlocks

Interlocking requirements regarding operating lever actuation must be designed to interrogation interlock principals: Operating lever(s) can only be inserted or



that actuating forces may only act on the components if this is permitted by the appropriate operating condition of the associated functional unit.

Digital switchgear interlock units are not accepted.

It must only be possible to remove or insert actuating levers in clearly defined positions “Close” or “Open”.

The interlocking should comply with the following interlocking conditions:

• Double acting interlock between busbar isolator and outgoing earthing switch

• Double acting interlock between busbar isolator and circuit breaker

• Double acting mechanical interlock between the switch disconnector and the outgoing earthing switch

• Double acting interlock between the cable compartment cover and the outgoing earthing switch (for cable testing, specific equipment must be provided to eliminate the outgoing earth).

Facilities provided for operational access to parts of the switchgear panel that contain live components shall be mechanically interlocked so that access to such parts is not possible unless all live parts have been rendered safe, either by a visibly applied earth connection or by being positively disconnected and screened from the remaining live parts.

Mechanical interlocks shall be provided to ensure positive and substantial protection against malfunction, and shall be so designed and constructed as to ensure dependable fail-safe operation.

Interlocks shall ensure that the disconnector cannot be moved or operated unless the circuit breaker is open.

Interlocks shall ensure that the circuit breaker cannot be closed unless the disconnector is fully in the “closed”, “isolated” or “earth” position.

Positive mechanical interlocking shall be provided to prevent inadvertent switching from the ON position to the EARTH position without a definite stop in the OFF position, or from the EARTH position to the ON position without a definite stop in the OFF position.

Access to the test terminals shall only be possible when the associated earth switch is in the EARTH position.

When the circuit test facility is in use, it shall not be possible to close the disconnector.

It is highly desirable that the making of the contacts in the circuit EARTH position shall be directly observable by the operator.



If the earthing of a circuit is not visible, the corresponding indication shall be directly coupled to the earthing mechanism, to ensure fail-safe indication.

If the switchgear panel is designed so that the circuit to be earthed is earthed through the main contacts of the circuit breaker, then the circuit breaker must be interlocked so that it cannot be tripped by the protection relays or SCADA control while the circuit is earthed.

An analysis shall be provided detailing the integrity of the interlocking system. The analysis shall include all possible failure modes and the controls employed to prevent an unsafe operation.

A table shall be produced of all possible and inhibited states the switchgear may occupy.

8.15 HV Cable Interface

8.15.1 General

Each circuit-breaker and switch panel shall be equipped with a front 11kV cable compartment interlocked with the ACCB providing for connection of 11kV cables.

The cable bushings shall be arranged side by side facing the front of the switchboard. Bushings shall be positioned suitable for connection of 3 core cables with tails of equal length to facilitate phase transposition without reterminating the cable.

All cable compartments shall be adequately sealed to prevent entry of vermin and dust to at least IP3X.

Each circuit breaker and switch panel is to provide the means to perform a DC cable test on the HV cables, without disturbing existing HV cable connections. See section 8.19 Circuit Test Facilities.

8.15.2 Fully insulated cable terminations

All cable termination compartments shall be suitable for dead-break, separable, fully insulated and shielded system for connection of HV cables. The separable, insulated, shielded connection system is to be compliant with AS 2629 (or equivalent IEC, EN) and relevant ratings specified in section 7.

Elastimold, bolted, field disconnectable are preferred. Railcorp to approve particular type.

8.15.3 Non fully insulated cable terminations

All cable termination compartments shall be suitable for air insulated termination. The compartment shall have at a minimum the clearances in accordance with AS 2067.



To provide protection against flashover due to rodents or high humidity Raychem removable and reinstallable elastomeric insulating boots (or approved alternative) for bushings type RCAB shall be fitted.

Cable terminations to be approved by Railcorp.

8.15.4 Cable compartment size

The cable compartment shall be required to accept single, three-conductor belted or three core dry type cables including: separately lead sheathed paper or XLPE insulated cables of up to 240mm2 cross section.

Where three phase cables are to be terminated the dimension of the cable compartment shall be such as to enable adequate clearances for crossing of cable cores.

All cable compartments shall be of dimensions such that full standard cable withstand power frequency tests as specified in Table 1 of AS 2650 can be conducted after cable termination is complete.

The cables shall enter the cable compartment from below. The minimum of one cable shall be achieved without sacrificing space for surge arrester equipment if required. The non standard configuration is top entry of power cables. Some situations may require this configuration if possible. Details of the cable connections options shall be nominated in the Technical Schedule at Appendix A

8.16 Surge arresters

The switchgear may be installed with short cable feeds from overhead lines.

Sufficient space shall be provided within the cable compartment of each feeder cubicle to install surge diverters if required for the specific feeding configuration.

Surge arrester type and restrictions shall be nominated in the Technical Schedule at Appendix A.

8.17 Circuit Earthing Facilities

Each panel shall be equipped with circuit earthing switches manufactured and tested the relevant standard nominated in chapter 7.

Earth switches shall be the integral type. It is preferred that earthing of the circuit cables is effected via a separately designed make-proof earthing switch. The earthing being located directly on the circuit cable and designed without interposing further switching devices.

The earthing system shall be designed and tested for making a live circuit with a prospective peak fault current to at least as specified in 7.1. Each circuit-earthing switch shall be mechanically interlocked with the corresponding circuit breaker or switch. Interlocking requirements are detailed section 8.14.



The earthing switch shall be fully rated for fault making to the requirements specified in chapter 7.

Each switch shall be provided with a failsafe indicating device to positively indicate whether it is in the OPEN OR EARTH position and the words "OPEN" and "EARTH" shall be used for the respective indication of these positions.

It is highly desirable the equipment shall be configured to allow the position of the earth switch contacts in the EARTH position to be directly observable. Appropriate illumination shall be provided. The preferred light source is white LED’s. It shall be possible to replace the light source without the need for isolating of HV equipment or significant disassembly of the switchgear.

8.18 Voltage detecting system

A voltage detection system (VDS) to (IEC 61243-5) with integrated display to detect: the dead state, the operating voltage and phase balance shall be provided for all HV circuits.

Suitable capacitive voltage dividers fitted in the cable connection area is acceptable to Railcorp.

Appropriate connections shall be provided to enable phase comparison in normal operating conditions.

A highly desirable feature is for remote indication of cable voltage status and interlocking with the earth switch. Interlocking should inhibit the earthing of live circuit conductors.

8.19 Circuit Test Facilities

Each circuit-breaker panel shall incorporate an integral type circuit test facility.

All test facilities shall be suitable for the application of dc test voltages associated with the after-installation testing of power cables, and shall be rated for the same system voltage as the switchgear.

The test facility shall facilitate the connection of test equipment with the circuit earthed and then allow the earths to be removed with the test equipment still connected.

It shall be possible to connect a hand applied earthing set to the circuit side of each circuit breaker panel for use in conjunction with test equipment. It shall be possible to apply or remove the earth connection independent of the application or removal of the test equipment connection. It is permissible that external removable accessories be used to achieve this function.

8.20 Padlocking

Facilities shall be provided to padlock:



• The disconnector in the closed, open and earth positions.

• The circuit-breaker in the open positions and the closed position while the disconnector is in the earthed position, and

• The circuit test facility, if applicable (see section 8.13 Auxiliary Equipment)

All padlocking facilities shall be suitable for padlocks with a 6mm shank diameter.

8.21 Floor fixing and penetration details

All equipment required for the fixing of the switchgear to the floor shall be provided, inclusive with the switchboard.

If no figures are included (and accepted by RailCorp) in the tender, It will be understood that a tolerance of ± 1.5mm over any 1m diameter circle and a tolerance of ± 6mm over the complete switchboard floor area will be provided by the principal.

8.22 Segregation of LV wiring in HV compartment

Any low voltage wiring within HV compartments shall be segregated, mechanically protected and installed to provide adequate protection from a HV fault damaging the LV circuits. Compliance with this requirement shall be detailed in technical schedule Appendix A.

8.23 Instruments, Transducers and Metering

8.23.1 General

All instruments, transducers and metering equipment that are required to be fitted shall comply with this section and the relevant requirements in EP 00 00 00 15 SP, Common Requirements for Electric Power Equipment.

All indicating instruments shall be flush-mounted industrial type instruments that comply with the requirements of the relevant of IEC standards: IEC 60051-1, IEC 60051-2, IEC 60051-3, IEC 60051-7, IEC 60051-8 and IEC 60051-9. The instruments shall be clearly visible and easily readable from a standing position in front of the panel.

Analogue instruments shall have a scale length of at least 90 mm. All instruments on a switchboard shall be scaled with the same type of characters of the same size. The instruments shall be 96mm x 96mm in size, with black scales on a white background.

All current-operated instruments shall be protected against continuous over current up to 120% of nominal value and high current surges up to the fault rating of the circuit breaker.



8.23.2 Current transducers

Each feeder/transformer panel shall have one current transducer connected to B∅ of the protection CT’s. The output of the current transducer shall be used to also drive the ammeter and then be connected to the SCADA RTU for remote indication.

The approved transducers to be used to measure current are of the 0 – 20mA type and are specified in RailCorp standard: EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network.

8.23.3 Voltage transducers

A voltage transducer shall be connected to each VT and connected to the SCADA RTU for remote indication.

The approved transducer to be used to measure voltage are of the 0 – 20mA type and are specified in RailCorp standard: EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network.

8.23.4 Ammeters

Ammeters shall have two scales that are essentially linear, the main scale shall allow for 120% of the primary current rating of the current transformer. The second scale will be equivalent to the main scale divided by 5, to allow reading of lower currents. A pushbutton fitted to the front of the ammeter shall activate the minor scale.

The current transformer ratio shall be clearly marked on the face of the ammeter.

The accuracy of ammeters shall be 3% or better and shall be stated in the Technical Schedule.

8.23.5 Voltmeters

Voltmeter shall have analogue indication with scales that have an indicating range of 80% to 120% of the nominal system voltages.

Where voltmeters that have a nominal range from 0% to 120% are required, this will be specified at time of order.

The nominal voltage shall be marked in red on the scale.

8.23.6 Watthour meter

kWh meters shall be three phase, with pulse output. The pulse output rate shall be 10 per kWh. Where required for revenue metering the kWh meter is to be connected to a metering CT of suitable rating and accuracy class.



8.24 Busbar and Circuit Protection

8.24.1 General

Protection schemes shall be in accordance with RailCorp specification EP 19 00 00 02 SP - Protection System Requirements for the High Voltage Network.

The protection scheme shall be specified in the protection concept which is required at time of switchboard procurement. See Appendix B.3

8.24.2 Feeder Protection

The protection for feeders will consist of overcurrent and earth fault protection and at strategic locations pilot wire protection will also be required.

The protection scheme shall be specified in the protection concept which is required at time of switchboard procurement.

8.24.3 System Transformer Protection

The relays and associated equipment for the protection of system transformers are normally located with the protection and control equipment for the higher voltage winding. The 11kV circuit breaker panel for a system transformer shall therefore be configured for connection to the required protection equipment located elsewhere. The neutral leakage relay is normally located on the 11kV panel.

8.24.4 Distribution Transformer Protection

The protection functions required for distribution transformers shall be implemented within the 11kV panel. Inputs from gas relays / gas over pressure voltage free contacts, low voltage equipment voltage free contacts and high temperature RTD’s inputs shall form part of the tripping circuit of the circuit breaker.

EP 19 00 00 02 SP - Protection System Requirements for the High Voltage Network.defines two schemes for distribution transformers:

Primary protection is a transformer differential scheme, with overcurrent & earth fault protection as backup.

Primary protection is overcurrent & earth fault protection - no backup.

Where a differential scheme is required terminals shall be provided for the connection of current transformers on the secondary side of the transformer and the protection equipment shall provide a trip output to trip the low voltage circuit breaker.



8.25 SCADA Indications and Controls

The SCADA alarms from equipment will be implemented by a combination of hard wiring and using the serial link on the electronic protection relays. The serial communication port on all electronic protection relays within a switchboard shall be connected together and wired to a terminal strip for connection to the the SCADA RTU.

Certain information is critical for system operation and must be independent on the protection relay or communication link to the RTU.

8.25.1 Binary Indication & ACCB Control

The following list details the SCADA alarms and control that are required to be hard wired to the RTU. There maybe other desirable alarms to the list below:

I/O Point Description. Hard Wired

Circuit Breaker (Open, Closed).

Isolator Position (Open, Closed)

Earthing switch Position (Open, Closed)

Circuit Breaker Alarms (eg spring charge motor).

Trip Circuit Supervision Alarms.

Gas/vacuum Monitoring Alarms

Protection Relay Watchdog Alarms

Bus Zone Trip

ACCB Open Control

ACCB Close Control

Table 22 – I/O Points

8.25.2 Analogue Indication

The following analogue indications shall be provided to SCADA:

• Circuit current ( at least 1 phase ) for each circuit breaker.

• Bus Voltage ( at least 1 phase ) for each switchboard.

Current transducers shall be provided to allow monitoring of primary circuit currents by SCADA. Transducers shall be connected in series with B phase of the protection CT circuit. Approved types and details are provided in specification EP 19 00 00 02 SP, Protection System Requirements for the High Voltage Network.



8.25.3 Controls

The following control functions from the SCADA system are to be provided for:

• Circuit Breaker Open (trip).

• Circuit Breaker Close.



9 Integrated System Support Requirements

9.1 Integrated Support Objectives

The switchgear manufacturer must establish and provide the information required to operate and maintain the equipment throughout its operational life, in a cost effective manner and to a level that is consistent with the planned operational performance and usage of the switchgear.

This includes:

• Specifying Maintenance Requirements,

• Spares Support,

• Operations and Maintenance Manuals,

• Training, and

• Support Equipment and Tooling.

9.2 Equipment Supplier Deliverable

The integrated support requirements are a significant deliverable in the procurement of new Switchgear. Manuals, training, documentation and other support deliverable's shall be in accordance with EP 00 00 00 12 SP, Electrical Power Equipment - Integrated Support Requirements.



10 Tests

Testing requirements are to be read in conjunction with the specification EP 00 00 00 15 SP, Common Requirements for Electric Power Equipment.

10.1 Routine tests

For each panel the following tests are to be carried out. Routine test reports shall be provided to Railcorp.

Switchgear routine tests as listed in:

• AS 2650, Clause 7

• AS 62271-100, Clause 7

• AS 60694 & AS 62271-200, all Clause 7. For non GIS clause 7.2 is applicable.

CT’s and VT’s

• AS 1675, Current transformer routine tests

• AS 1243, Voltage transformer routine tests

10.2 Type tests

The results of type tests as required in:

• AS 2650

• AS 62271-100

• AS 62271-200

• AS 62271-200, appendix A7, test report for internal arc

Shall be made available by the supplier upon request.

Test certificate details, demonstrating compliance with the above standards, including the date, results and name of the testing body shall be supplied in the Technical Schedule at Appendix A.

Type test certificates for each of these tests will be accepted where it can be demonstrated that the switchgear supplied is of a similar design to previously type tested switchgear.



11 Data Set associated with the Equipment

The following data shall be supplied by the manufacturer and maintained for the switchgear. This data will remain the property of RailCorp.

11.1 Information

AS 2650, Appendix A2, drawings: This is the base set of drawings required.

Additional information and requirements as a deliverable under equipment supply is documented in the following specifications:

• EP 00 00 00 12 SP, Electrical Power Equipment – Integrated Support Requirements.

• EP 00 00 00 15 SP, Common Requirements for Electric Power Equipment.

• EP 19 00 00 02 SP, Protection System Requirements for High Voltage Network.

11.2 Technical Schedule at Appendix A

The information listed in the technical schedule at Appendix A, supplied by the manufacturer, shall be maintained for each switchboard.

11.3 Life Cycle Costing

All the data and assumptions pertaining to the determination of the whole-of-life cost calculations shall be recorded.



Appendix A Technical Schedule

The manufacturer shall supply the information listed in this technical schedule.

Item Description Tenderer Supplied Information

1. General Switchgear Information:

Manufacturer

Country of origin

2. Catalogue/type Designation

Feeder ACCB (code F)

Bus-coupling ACCB (code B)

Bus-tie cable ACCB (code T)

System Transformer ACCB (code ST)

Distribution Transformer ACCB (code t)

Capacitor/Harmonic Filter ACCB (code C)

Feeder network switch (code D)

Feeder (non auto) ACCB (code Fna)

3. Switchgear Ratings:

Rated System Voltage (Ur)

Rated frequency (fr)

Rated Busbar Normal Current (Ir)

Switchboard Class

Busbar Insulation medium

Rated lightning impulse withstand voltage (Up)

Common value (kV)

Across the isolating distance (kV)

Rated short-duration power-frequency withstand voltage (Ud)

Common value (kV)

Across the isolating distance (kV)



Rated short time withstand current (Ik) (for main and earthing circuits)

Rated peak withstand current (Ip) (for main and earthing circuits)

Rated duration of short circuit (tk) (for main and earthing circuits)

Internal Arc Classification (IAC)

Arc test current (kA)

Arc test current duration (s)

Rated Short Circuit Making Current (kA)

Rated short circuit breaking current (kA)

Short duration power frequency withstand voltage


Partition class (as defined in AS 62271 – 200, Annex A)

Partial discharge level of complete switchboard including all components

Rated normal current (Ir)

Feeder ACCB (code F)

Bus-coupling ACCB (code B)

Bus-cable tie ACCB (code T)

System Transformer ACCB (code ST)

Distribution Transformer ACCB (code t)

Capacitor/Harmonic Filter ACCB (code C)

Feeder (non auto) ACCB (code Fna)

Feeder network load switch (code D)

Provide applicable derating factors for ambient conditions to a maximum of 50°C (derating factors should be in a form of table or graph).

Interrupter type Vacuum / SF6


Number of trip coils

Number of close coils

Breaking time (max)



Command response time both ON and OFF (max)

Rated switch sequence

Type of circuit-breaker closing mechanism offered

Circuit breaker mechanical durability class

Circuit breaker electrical durability class

Supply voltage, peak power and steady power of the spring charge motor (where applicable)

Voltage and peak power ratings for the continuous operation of the circuit-breaker coils

Number of circuit breaker spare auxillary contacts

Normally Open

Normally Closed

Rating of ACCB spare auxillary contacts

Description of all operational and safety interlocking arrangements

Table of all possible and inhibited states that the circuit breakers and switches in the switchgear may occupy

Analysis demonstrating the integrity of all interlocking arrangements which includes an analysis of all possible failure modes and the controls designed in to manage them

Does the circuit-breaker panel include in-line off-load disconnectors?

Description of the panel busbar interconnection arrangements

Type, ratings, details of circuit Votage detection system

Surge arrester types accommodated

Surge arrester mounting details/restrictions.

Details of Segregation, mechancal protection of LV wiring in HV compartments

Internal arc fault detection and protection scheme details. If offered as alternative to high impedance bus protection.



4. HV Cable Access, Testing & Termination Details

Provide details of how the HV cables are accessed.

Maximum size and number of HV cables that can be terminated in each circuit-breaker panel. Clearly specify clearances between each cable termination of each phase. Provision of a detailed dimensioned drawing of the arrangement is required.

Type of cable termination offered. Specify manufacturer, model and full details of separable insulated connector. Detail shielding arrangement to be included

Type of circuit test facility offered.

Describe the test plugs



5. Gas Insulated Switchgear

Type of gas used for insulation

In which compartments is the gas used?

Provide details of the gas pressure monitoring system/device.

Quantity of the SF6 to be used in each separately filled compartment?

Specify the degree of SF6 gas tightness for the switchgear

If the circuit-breaker is a vacuum type state the method of indicating vacuum loss (if any)



6. Earth Switch & Earthing Facilities


Rated make fault current rating

Earth switch mechanical durability class

Earth switch electrical durability class

Provide details of the circuit earthing facilities offered including the method of indicating the position of the earthing switch and guaranteeing the integrity of that indication.

Provide details of the earthing bars for feeder ACCB panels, and how the requirements of insulated cable screen earth bar is met.

7. Network load Switch (code = D)

Rated System Voltage (Ur)


Details of fault making switch offered

Is the switch offered 2-way or 3-way?

Switch mechanical durability class

Switch electrical durability class

Load break capability



Load make capability

Method of Interlocking with fully rated earth switch



8. Details Relating To Capacitor/Harmonic ACCB

Has the switchgear been used for un-earthed, straight (no reactors) capacitor bank switching previously?

Has allowance been made for the capacitor bank circuit breakers to be pre-conditioned ready for service with negligible probability of re-strike?

Has the switchgear been tested for 150% DC offset and nominal AC voltage across the open contacts, successfully passing with no discharge in the contact dielectric?

Has allowance been made for capacitor bank energisation currents to be reviewed for use based on the particular site design?

9. Low Voltage Panel/Equipment

Where are the protection relays, test blocks, meters and low voltage fuses located ?

Describe LV termination and cable access arrangements

Rating plate attachment method:

Labels attachment method

Provide details of paint coatings on the switchgear.

Provide details of colours of custom paint coatings available.



10. Current Transformers (CT)

Type of CT’s being offered

Where are the CT’s located and how are they mounted.

Detail the physical space limitations

Are the CT’s offered the same ratio & class as specified in the standard? If not please provide details of variances.



11. Busbar Protection Scheme

Is the busbar protection scheme offered a high impedance scheme ?

YES/NO

If the busbar protection scheme offered is not a high impedance scheme please provide details of the alternate scheme including:

detailed operating documentation

detailed maintenance documentation

copies of test certificates



12. Voltage Transformers

Describe the physical location of the VT’s (busbar and incomer) and relevant dimensions.

How are the VT’s connected/isolated ?

Are fuses fitted to the primary side of the VT’s.

Describe the method(s) for simulation of system earth faults during test & commissioning of directional relays.

Details of voltage transformers offered:

name of manufacturer

ratio & class

burden,VA

voltage factor

location and type of fuses



13. Site Installation Details

How are the switchboards transported to site ? Detail whether panels are assembled on site and then gassed or assembled and gassed prior.

Are there any site specific requirements for installation (eg. floor surface requirements)

Provide details of how the panels/switchboards are lifted and moved into position on site.

14. Switchboard Dimensions & Weights

Switchboard – Provide general arrangement drawings showing overall dimensions (h, w, d in mm), cable termination locations and required space for access and arc venting requirements for ST1FT, ST2FtT, 1FnaD, 1FD configurations.

Required side clearance of switchboard (mm)

Required rear clearance of switchboard (mm)

Required clearance on top of switchboard (mm)

Required clearance at front of switchboard for installation and removal (mm)

Recommended cable trench width (mm)

Depth of protrusions into cable trench (if applicable)

Weight of heaviest configuration (kg)



15. Reliability Data:

Failure Modes (for early, Normal life & wear out periods)

Mean Operating Hours between failure modes

Mean Time To Repair. Provide details of any special requirements, test and support equipment etc

Number of units in service in Australia

Period (years) this model/type has been available for purchase.

Estimated period before replacement with new model.

Number of units in service worldwide



Appendix B RFT Checklist

Appendix B.1 Application

The following material is for guidance in the preparation of a Request for Tender for this type of equipment. This checklist itself is not intended to directly form part of any contract.

This section to be read in conjunction with the RFT Checklist in specification EP 00 00 00 15 SP, Common Requirements for Electric Power Equipment.

Appendix B.2 Information to be Sought From the Tenderer

• Integrated Support information as per RailCorp Standard

• Tenders to complete and submit Technical Schedule at Appendix A



Appendix B.3 Information to be supplied at time of order

When needed for procurement of equipment for a particular location, in addition to the general requirements in this specification the following information related to the particular site shall be supplied as part of the order:

• Approved (for purchase) HV operating diagram for each substation. This diagram is under configuration control.

• Required quantity and associated switchboard code. This information must be consistent with the approved (for purchase) operating diagram. The position of each functional unit within the switchboard will be in accordance with the approved (for purchase) operating diagram.

• The number of sets, position and specification of the CT’s, protection relay and protection scheme will be detailed in the authorised protection concept (approved for purchase) associated with each switchboard. The protection concept (approved for purchase) must be provided with each switchboard order.

• DC control voltage to be specified for each switchboard order. Choice is either 125 V dc or 48 V dc. This will be a requirement in the authorised protection concept for the location. Associated protection relays, RTU, switchgear etc will need to be compatible with the location battery supply.

• Busbar rating of 630 or 1250 Amp.

• Panel location of busbar high impedance unit scheme components: relay, test block, MTM relay, links and associated wiring.

• The specific configuration of instruments, transducers and metering equipment (voltage, current and energy), to be installed on switchgear panels.

• The required number of cables and size per phase, per panel.

• Feeder specific surge arrester requirements.

• Any site specific restrictions on the dimensions or placement of the switchgear.

• Special transport or unloading requirements.

• Notice that the supplier will be required to provide appropriate seals for switchboard and associated components to prevent contamination during storage and transport.

• Requirement for specific deliverables including:

• Installation and on-site operational testing if to be carried out by the supplier



• Requirements for training

• Requirements for spares

• Recovery and replenishment of SF6 gas after its service life (must be rendered by the supplier of SF6 switchgear).

• Two spare sets of fuses for each voltage transformer.

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