EirGrid Commissioning Procedures Rev 0

Document Reference: XDS-GCP-00-001-R0

110/220/400kV EirGrid Commissioning

Procedures

Revision History

Revision Date Description Originator Approvers

R0 25/04/14

First Issue

ESBI – see page 3

Paul Moran &

Ricardo

Barandika

COPYRIGHT © EirGrid All rights reserved. No part of this work may be modified or reproduced or copied in any form or by means - graphic,

electronic or mechanical, including photocopying, recording, taping or information and retrieval system, or used for any

purpose other than its designated purpose, without the written permission of EirGrid

ESB International, Stephen Court, 18/21 St Stephen’s Green, Dublin 2, Ireland.

Phone +353 (0)1 703 8000

www.esbi.ie

EirGrid Commissioning Procedures

Document No.: DP-040-006

Date: 25 April 2014

http://www.esbi.ie/

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File Reference: DP-040-006

Client / Recipient:

EirGrid

Project Title: EirGrid Commissioning Procedures

Report Title: EirGrid Commissioning Procedures

Report No.: DP-040-006

Volume: 1 of 1

Prepared by: Dan Catanase, Robert Arthur & Callaghan Ahern

16/04/2014

Title: Asset Management Services (AMS)

Verified by: Niall Kearns 23/04/2014

Title: Manager, Commissioning & Protection Maintenance, AMS

Approved by: Mick Sherlock 24/04/2014

Title: Engineering Manager, AMS

Copyright © ESB International Limited

All rights reserved. No part of this work may be modified, reproduced or copied in

any form or by any means - graphic, electronic or mechanical, including

photocopying, recording, taping or used for any purpose other than its designated

purpose, without the written permission of ESB International Limited.

Template Used: T-020-007-ESBI Report Template

Change History of Report

Date New Revision Author Summary of Change

13/03/2014 00 DC, RA & CA EirGrid Commissioning Test Procedures Draft

22/04/2014 01 DC, RA & CA Final Document, Agreed Comments Added

DP-040-006

ASSET MANAGEMENT SERVICES

The purpose of this document is to define a list of commissioning procedures associated with EHV & HV Substation plant, protection and control systems.

The procedures incorporated in this list have been developed to comply with the requirements of the Infrastructure Agreement between EirGrid and ESB Networks

The procedures specify, at a high level, the minimum commissioning test requirements to be carried out by the commissioning service provider on the relevant items of plant and substation systems.

In compliance with best international practice, the commissioning service provider should provide detailed method statements outlining the methodologies associated with the procedures. They should also provide detailed tests result records to support these commissioning tests.

Date: 25/04/2014

ESBI Asset Management Services – Commissioning Procedures

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SUMMARY OF COMMISSIONING PROCEDURES

PRIMARY PLANT and CIRCUITS:

1. Power Transformers 2. Circuit Breakers 3. Instrument Transformers 4. Disconnects 5. Surge Arresters 6. Lines/Cables/Busbar phasing 7. Interlocking 8. Earth Grid

SECONDARY CIRCUITS & PROTECTION

9. AC/DC Substation Systems 10. Feeder/Bay Impedance & Associated Protection Functions 11. Feeder/Bay Differential & Associated Protection Functions 12. Feeder/Bay Overcurrent& Associated Protection Functions 13. Transformer Differential & Associated Protection Functions 14. Transformer Non Current Protection Functions 15. Synchronising schemes 16. Station Busbar/CBF protection 17. Station SCADA systems, remote control and indications

HV Lines HV Cables


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Table of Contents

1 Power Transformer Commissioning Procedure 11

1.1 General 11

1.2 Procedure 11

1.3 Visual Inspection 12

1.4 Clearances 12

1.5 HV Insulation Resistance Tests. 12

1.6 HV Insulation Test. 12

1.7 Frequency Response Analysis (FRA) 12

1.8 Turns Ratio Test 13

1.9 Vector Group Test 13

1.10 Winding Resistance Tests 13

1.11 Internal / bushing CT’s (if fitted) 13

1.12 Oil\Winding Temperature Monitoring Devices 13

1.13 Mechanical Operations Checks 13

1.14 Insulating Oil Quality 14

1.15 Automatic Voltage Regulation 14

1.16 Protection Device Tests 14

1.17 Final Checks 14

2 Circuit breaker Commissioning Procedure 15

2.1 General 15

2.2 Commissioning Tests 15

3 Instrument Transformer Commissioning Procedure 18

3.1 General 18


4 Disconnect Commissioning Procedure 21

4.1 General 21


4.3 Disconnect tests 21

5 Surge Arrestor Commissioning Procedure 24

5.1 General 24


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6 Lines, Cables and Busbar Phasing Procedure 26

6.1 General 26

6.2 Safety considerations 26

6.3 Site Data 27

6.4 Phasing Tests 27

6.5 Final Checks 28

7 Interlocking Commissioning Procedure 29

7.1 General 29

7.2 Safety considerations 29

7.3 Site Data 30

7.4 Interlocking Tests 30

7.5 Final Checks 31

8 Earth Grid Commissioning Procedure 32

8.1 General 32

8.2 Procedure 32

8.3 Earth grid tests 32

9 AC and DC circuits Commissioning Procedure 35

9.1 General 35

9.2 Scope 35


9.4 Site Data 37

9.5 Final Checks 37

10 Feeder Impedance Protection Commissioning Procedure38

10.1 General 38

10.2 Procedure 39

11 Feeder Differential Protection Commissioning Procedure 43

11.1 General 43

11.2 Procedure 44

12 Feeder Overcurrent Protection Commissioning Procedure 47

12.1 General 47

12.2 Procedure 47


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13 Transformer Differential Protection Commissioning Procedure

51

13.1 General 51


14 Transformer Non Current Protection Commissioning Procedure

55

14.1 General 55

14.2 Procedure 55

15 Synchronising Commissioning Procedure 59

15.1 General 59

15.2 Procedure 59

15.3 Final Tests 61

16 Station bus zone / circuit breaker failure protection

commissioning procedure 63

16.1 General 63

16.2 Procedure 63

17 Station SCADA systems, remote control and indications 67

17.1 General 67

17.2 Procedure 67

17.3 Final Tests 69

17.4 On Load Tests 69

18 HV Lines 71

18.1 Line Corridor 71

18.2 Lattice Steel Tower 73

18.3 Steel Monopole 75

18.4 110 kV Braced Angle Woodpole 77

18.5 110 kV Intermediate Woodpole 79

18.6 Conductor & Hardware 80

18.7 Insulator & Hardware 81

18.8 Jumpers 82

18.9 Station lead-in connection 83

18.10 Station Busbar 84


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19 HV Cables 86

19.1 Visual Inspection 86

19.2 Sheath Test 87

19.3 220 kV & 400 kV HV AC Core Test 88

19.4 Oil Filled Impregnation Test 89

19.5 Oil Filled Cable Flow Test 90


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PRIMARY PLANT AND CIRCUITS


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1 Power Transformer Commissioning Procedure

1.1 General

1.1.1 Scope

This document describes the test procedure to be performed on all high

voltage power transformers installed on the transmission network. The tests

described in this document should be performed prior to commissioning and

when applicable during subsequent preventive maintenance. The

appropriate tests from this document shall also be performed after the

replacement of any equipment forming part of the power transformer.

These tests may also be used in conjunction with other specialised tests

recommended by power transformer manufacturer for corrective

maintenance tasks and condition assessment.

1.1.2 Object

The object of this document is to provide a minimum set of test procedures

that ensure the integrity and correct operation of all power transformers.

1.1.3 Reference Documents

Transformer Commissioning Test Sheet

Power Transformer reference manual

IEC 60076, IEC 60296

1.2 Procedure

1.2.1 Power Transformer Tests

The following tests shall be performed on the equipment that comprises the

power transformer as per section 1.1.1.

All test results and site data shall be recorded on the relevant test results

form.

All non compliances shall be investigated and rectified as necessary. If a

non compliance cannot be rectified, or any doubt exists over the


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serviceability of any component in the power transformer the component

shall be replaced.

1.2.2 Site Data

Record all necessary transformer data as per relevant Commissioning Test Sheet

Confirm that nameplate rating corresponds to Single Line Diagram.

1.3 Visual Inspection

The power transformer shall be examined to confirm the following:

No physical damage

Paintwork in good condition

Oil levels are correct and no leaks present.

Earthing requirements are as specified.

1.4 Clearances

Check clearances to be in accordance with Safety Standards/ Rules or IEC

60071

1.5 HV Insulation Resistance Tests.

The insulation resistance shall be measured between each transformer

winding and between each winding and earth.

If the transformer core is accessible, the insulation resistance shall also be

measured between the transformer core and earth.

1.6 HV Insulation Test.

High voltage insulation loss measurements shall be conducted on windings,

bushings and test taps where appropriate.

1.7 Frequency Response Analysis (FRA)

An FRA test shall be carried out on the HV and LV windings.

WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO

WORKING ON PRIMARY EQUIPMENT.


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1.8 Turns Ratio Test

Tests shall be performed on all taps of all transformer windings to confirm

that the transformer turns ratio is as per manufacturer’s specification.

1.9 Vector Group Test

Test shall be performed to confirm that the transformer vector group is as

per nameplate.

1.10 Winding Resistance Tests

Tests shall be performed on all taps of all transformer windings to confirm

that the transformer winding resistance is as per manufacturer’s

specification.

1.11 Internal / bushing CT’s (if fitted)

Interwinding / earth megger tests

Verify polarity

Ratio test

Magnetisation curve test

Secondary connected burden test

1.12 Oil\Winding Temperature Monitoring Devices

Tests shall be performed to confirm the accuracy of all oil and winding

temperature gauges and thermostats by heating the probe sensors in a

suitable temperature chamber. Gauge accuracy should be verified at

various temperatures throughout the range of the gauge. The winding

temperature thermal image (i.e. winding temperature gauge rise above oil

temperature) shall be confirmed using secondary current injection as per

manufacturer’s specification. Alarms and trips generated by these devices

should be tested where applicable.

1.13 Mechanical Operations Checks

The following mechanical operational checks shall be performed as

applicable.

Confirm the correct operation of the tap changer mechanism for raise and lower operation in manual and automatic mode.

Confirm that all fans operate correctly in right direction and in manual / automatic mode.

Confirm that oil pumps, where applicable, operate in right direction and in manual / automatic mode.


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1.14 Insulating Oil Quality

Confirm that oil samples have been taken, tested and evaluated from the

following compartments;

Main tank top & bottom

Main Conservator

Tap-changer conservator

Diverter switch compartment

1.15 Automatic Voltage Regulation

Tests shall be performed to confirm the correct operation of all transformer

voltage regulating relays.

1.16 Protection Device Tests

All protection relays and devices shall be tested.

Transformer differential protection and restricted earth fault protection proven stable by primary injection test

All alarm signals and trip signals shall be verified from source.

1.17 Final Checks

On completion of testing confirm the following:

All primary connections have been torqued and all secondary connections are tight

Test sheet has been completed; all tests assessed and signed off.

All test equipment has been removed.

All labelling, and warning notices have been applied.


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2 Circuit breaker Commissioning Procedure

2.1 General

2.1.1 Scope


voltage circuit breakers installed on the transmission network. The tests

described in this document should be performed as part of the

commissioning process and when applicable during subsequent preventive

maintenance. The appropriate tests from this document shall also be

performed after the replacement of any equipment forming part of the circuit

breaker.


recommended by circuit breaker manufacturer for corrective maintenance

tasks and condition assessment.

2.1.2 Object


that ensure the integrity and correct operation of all circuit breakers.


Circuit Breaker manufacturer reference manual

Circuit Breaker Commissioning Test Sheet

IEC 62271-100

2.2 Commissioning Tests

2.2.1 Circuit breaker Tests


circuit breaker as per section 2.1.1

All test results and site data shall be recorded on the relevant

commissioning test sheet.




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serviceability of any component in the circuit breaker, the component shall

be replaced.

2.2.2 Site Data

Record all necessary circuit breaker data as per relevant commissioning test sheet.

Confirm that nameplate rating corresponds to Single Line Diagram and substation nominal AC/DC voltages.

2.2.3 Visual Inspection

The circuit breakers shall be examined to confirm the following:

supporting metal-work and control cabinet effectively earthed

breaker identified and phases marked

breaker firmly bolted down

condition of paintwork and galvanising satisfactory

manufacturer's operating instructions for this equipment available on site

SF6 warning and SF6 manual operation restriction notices been affixed

2.2.4 Clearances


60071

2.2.5 Insulation Resistance Tests (Megger)

The insulation resistance shall be measured to earth, between phases and

across the CB open contacts.

2.2.6 HV Insulation Test.

Where required, a high voltage Tan Delta (power factor loss test) shall be

carried out on each circuit breaker pole.

2.2.7 Contact Resistance tests.

The contact resistance, static for main contacts and current path, and

dynamic for arcing contacts shall be measured.




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2.2.8 Timing tests

The circuit breaker closing and opening operating times shall be measured

and compared to the manufacturer’s specification. Where applicable, pole

synchronism shall be checked also.

2.2.9 Circuit breaker mechanism tests

For motor wound spring circuit breakers, check minimum energy of spring,

flywheel slip, and force to operate close and trip latches.

For pneumatic mechanisms, test operation of compressor stop/start, reclose

operation and low pressure lockout. Where applicable, test operation of

safety valve.

For hydraulic mechanisms, test operation of motor stop/start, reclose

operation and low pressure lockout. Where applicable, test Nitrogen priming

pressure and operation of safety valve.

2.2.10 SF6 Circuit breakers

Test SF6 gas purity and moisture measurement

Test operation of densimeter alarms and block function.

2.2.11 Functional checks

Test operation of the circuit breaker in manual, local, remote and SCADA

modes.

Test trip operation from protection relays.

Test anti pumping operation.

Test pole discrepancy operation if applicable.

AC Supply. Heater and power socket if applicable.

2.2.12 Final Checks


Test sheet has been completed, all tests assessed and signed off

HV connections torqued


All labelling, and warning notices have been applied


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3 Instrument Transformer Commissioning Procedure

3.1 General

3.1.1 Scope


voltage instrument transformers installed on the transmission network. The

tests described in this document should be performed prior to

commissioning and when applicable during subsequent preventive


performed after the replacement of any equipment forming part of the

instrument transformer.

These tests may also be used in conjunction with other specialised tests for

corrective maintenance tasks and condition assessment.

3.1.2 Object


that ensure the integrity and correct operation of all instrument transformers.


Instrument transformer manufacturer reference manual

Instrument transformer Commissioning Test Sheet

IEC 60044


3.2.1 Instrument Transformer Tests


instrument transformer as per section 3.1.1


commissioning test sheet form.




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serviceability of any component in the instrument transformer, the

component shall be replaced.

3.2.2 Site Data

Record all necessary instrument transformer data as per relevant test result forms.


Confirm orientation is as per Single Line Diagram


The instrument transformers shall be examined to confirm the following:

No physical damage.

Oil levels are correct and no leaks present.


3.2.4 Clearances


60071


The insulation resistance shall be measured:

between primary winding to earth

between each secondary winding and earth

between secondary windings

3.2.6 Current Transformers

Verify polarity for all cores.

Verify turns ratio. If more than 1 ratio is available, all combinations should be verified.

Conduct magnetisation curve test on all cores

Measure connected burden for each core

Conduct connected secondary wiring integrity, polarity and functionality checks




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3.2.7 Voltage Transformers

Verify polarity.

Verify turns ratio.

Conduct connected secondary wiring integrity, polarity and functionality checks

3.2.8 Final Checks


Secondary wiring connections are tight






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4 Disconnect Commissioning Procedure

4.1 General

4.1.1 Scope


voltage disconnects installed on the transmission network. The tests

described in this document should be performed as part of the

commissioning process and when applicable during subsequent preventive


performed after the replacement of any equipment forming part of the

disconnect.


recommended by the disconnect manufacturer for corrective maintenance

tasks and condition assessment.

4.1.2 Object


that ensure the integrity and correct operation of all disconnects.


Disconnect manufacturer reference manual

Disconnect Commissioning Test Sheet

IEC 62271-102


4.3 Disconnect tests


disconnect as per section 4.1.1





serviceability of any component in the disconnect, the component shall be

replaced.


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4.3.1 Site Data

Record all necessary disconnect data as per relevant test result forms.

Confirm that nameplate rating corresponds to Single Line Diagram and substation nominal AC/DC voltages.


The disconnects shall be examined to confirm the following:

No physical damage.


No leaks (for air operated disconnects)

4.3.3 Clearances

Check clearances – in open and closed position – to be in accordance with

Safety Standards/ Rules or IEC 60071


The insulation resistance shall be measured to earth in open and closed

position and across open contacts.

4.3.5 Setting Up

Test that the alignment and synchronising of primary and secondary contacts is correct.

Verify that the disconnect operates smoothly.

Verify linkage and drive shaft adjustment points to be appropriately locked (pinned if applicable) to prevent slippage during service.

4.3.6 Function Checks

Test that the disconnect operates correctly in manual/local/remote mode as applicable.

Verify operation of interlocks

Verify correct auxiliary contact functionality and mode.

AC: heater and power socket if applicable

4.3.7 Final Checks





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5 Surge Arrestor Commissioning Procedure

5.1 General

5.1.1 Scope


voltage surge arrestors installed on the transmission network. The tests

described in this document should be performed prior to commissioning and

when applicable during subsequent preventive maintenance. The


replacement of any equipment forming part of the surge arrestor.


recommended by the surge arrester manufacturer for corrective


5.1.2 Object


that ensure the integrity of the surge arrestor.


Surge Arrestor Commissioning Test Sheet

IEC 60099 Part 1-8


5.2.1 Surge Arrestor tests


Surge Arrestor as per section 5.1.1


form.



serviceability of any component in the surge arrestor, the component shall

be replaced.


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5.2.2 Site Data

Record all necessary surge arrestor data as per relevant test result forms.



The surge arrestor shall be examined to confirm the following:

No physical damage.


Counter reading recorded

5.2.4 Clearances


60071


The insulation resistance across each stack. (If more than one stack).

The insulation resistance from top of surge arrestor shall be measured to

the base.

The insulation resistance between the surge arrestor base and earth.

The ammeter reading will be verified.

5.2.6 Final Checks





Primary connections torqued.




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6 Lines, Cables and Busbar Phasing Procedure

6.1 General

6.1.1 Scope

The purpose of this procedure is to describe the test methodologies

associated with checking the correct phase correspondence between two or

multiple ends of a transmission line and for HV substations busbars.

It is necessary to carry out this phasing test after conductors have been

altered\changed or repaired at any part of the line or station busbar, as well

for all new installations.

6.1.2 Object

It is intended to prove the continuity of the conductors, that there is no

connection between phases, that the phasing is still as is designated at both

ends of the line and that all local earths have been removed.


ESB safety rules

6.2 Safety considerations

If there is any risk of thunder at any point of the transmission line the test

may not take place.

The insulation tester connections may only be applied to the line while the

line is earthed by applying the main station earths.

Care must be taken to observe the limits of close proximity while the

insulation tester is connected to the earth free line.

If the level of induced voltage present on the line is deemed to present a risk

to the application of the insulation tester then alternative methods must be

used.


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6.3 Site Data

It is important to observe the phasing arrangement within substation and

check against the approved design and ESB standard substation layout.

6.4 Phasing Tests

6.4.1 Phasing HV Lines and Cables

Prerequisites for carrying out this test:

Line switched out and isolated

ESB operators in place at both ends of line

Telemess in place between end to end ESB operators stating points of disconnection, that main earths have been applied, and that they may be removed for test purposes

Commissioning engineer in place at the local end of line

The following tests will performed and recorded in the appropriate

commissioning test reports. The tests should cover at minimum the following

conditions:

1. For all two phase combinations should be proven that there is no physical

contact between any two of them

2. Each phase should be checked for continuity between ends

3. If phasing is tested between two substations, phasing shall be proven form

busbar to busbar

6.4.2 Phasing busbars in HV substations

In AIS substations, the correct phase correspondence shall be verified for

each busbar section and also between different busbar sections across

coupler(s)

For GIS substations, the phase match shall be confirmed on every bay for

each busbar section from cable sealing end to busbar and between busbar

sections across coupler(s). For substations with more than one busbar,




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phasing validation applies for every busbar, between busbars and across

coupler(s) for all possible combinations.

6.5 Final Checks


Test sheets have been completed; all tests assessed and signed off.




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7 Interlocking Commissioning Procedure

7.1 General

7.1.1 Scope

This document describes the test procedure to be performed to test the

interlocking conditions in all HV substations. The tests described in this

document should be performed as part of the commissioning works.

Substations shall be provided with a full interlocking scheme to ensure that

all disconnectors, fixed earthing switches (or other interlocked earthing

devices) and, where required, circuit-breakers are operated in the correct

sequence so that personnel do not endanger themselves and/or the integrity

of the transmission system by incorrect or inadvertent operation of

equipment. Interlocking systems shall, where practicable, be fail-safe. They

shall not be defeatable without the use of a purpose designed override

facility which shall be lockable with safety locks.

7.1.2 Object

The purpose of these tests is to establish that the cubicle/substation

equipment and control interlocks are functioning correctly.


ESB safety rules

ESB Code of practice No.B3 Operational tests for transmission station

equipment.

Interlocking conditions document provided by the client

7.2 Safety considerations

During the tests, the cubicle/substation equipment should be considered

live.

In setting out the conditions and sequence of testing, consideration should

be given to the possible failure of the interlocking condition under test.

All test conditions shall be recorded on the relevant test results form.

All non compliances shall be investigated and rectified as necessary.


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7.3 Site Data

It is important to make sure all the following information is available:

Substation Single Line Diagram

Approved interlocking conditions sheet

Interlocking commissioning test sheet

7.4 Interlocking Tests

The following tests will performed and recorded in the appropriate

commissioning test reports. The tests should cover at minimum the following

conditions:

All interlocking tests must conform to the approved interlocking

conditions associated with the station issued by the station designer

Correct type of secondary contacts of the HV equipment

(disconnectors) being used. Contact multiplication is not allowed

For every interlocking condition a positive and a negative test should

be carried out.

All permissive and blocking conditions should be checked in both

direction – for opening and closing conditions

Interlocking between circuit-breakers and disconnectors to ensure

disconnects do not make or break load currents

Interlocking between disconnectors and earthing switches to ensure

that earthing switches cannot be closed on to a locally energised

circuit and cannot be energised, when closed, by operation of

disconnectors

Ensuring correct sequence of on load busbar transfer switching

operations at multiple busbar substations

Ensure that all bays have been integrated into the general substation

interlocking scheme

Cross transformer interlocking tests to ensure that is not possible to

start energising the transformer when the earth was applied on either

side and vice versa, is not possible to close an earth disconnect

when the transformer is live from either side.

For microprocessor based interlocking, the system shall operate in

accordance with the agreed logic table for the application. Any




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combination of inputs for which an output has not been specified

shall give no output.

7.5 Final Checks





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8 Earth Grid Commissioning Procedure

8.1 General

8.1.1 Scope

This document describes the test procedure to be performed on the

substation earth grid for all high voltage substations. The tests described in

this document should be performed prior to commissioning and when

applicable during subsequent preventive maintenance. The appropriate

tests from this document shall also be performed after any interference with

the existing substation earth grid.

8.1.2 Object


that ensure the integrity of the substation earth grid.


Substation Pre-commissioning Procedures

Earth Grid Test Sheet

IEEE Std 80-2000, IEEE Std 81-1983, EN 50522-2010

8.2 Procedure

The existence of the High Voltage (HV) infrastructure creates a special set

of safety circumstances. The earth grid system is one of the main elements

to mitigate any unsafe conditions. Commissioning the earth grid certifies that

the implemented system fulfils to the pertinent necessities.

8.3 Earth grid tests


substation earth grid.


form.

All non compliances shall be investigated and rectified as necessary.


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8.3.1 Site Data

It is important to make sure all the following information is available:

Site layout

Grid layout

Maximum fault current

Clearance time

Back up time

Location of the feeding station

Near-by utility

Communication network in the area

Feeding characteristics

Any special considerations

Surrounding

If is vital to evaluate the gathered information with the one from the earthing design

report. It is important to choose an injection set that will prevent any interference

from occurrence especially the interference from another transmission mains or

substations.

8.3.2 Earth Grid Tests

The following tests will performed and recorded in the appropriate commissioning

test reports.

1. Earth grid resistance value

2. Split factor (under the existing of a return path)

3. Actual Touch voltage

4. Actual Step voltage

5. Actual EPR (Earth Potential Rise) contour

6. Actual transfer voltage to near by infrastructure

7. Earth grid continuity

8.3.3 Final Checks








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SECONDARY CIRCUITS & PROTECTION


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9 AC and DC circuits Commissioning Procedure

9.1 General

This procedure has been prepared to cover the commissioning activities for all HV Substations AC/DC common services.

9.2 Scope

This document describes the test procedure to be performed on station

common AC systems, batteries and chargers installed in transmission

stations. The appropriate tests from this document shall also be performed

after the replacement of any equipment forming part of the above systems.


recommended by the battery/charger manufacturer for corrective


9.2.1 Object


that ensure the integrity and correct operation of all station AC and DC

common systems.


AC commissioning Test Sheet

Station Battery Commissioning Test Sheet

Station Battery Charger and Battery Supervision Test Sheet

Battery and Charger manufacturer instructions


9.3.1 Substation AC systems

The following tests shall be applied to all panels being part of the substation

common AC systems:

Check against the design the correct type and rating for all AC

MCB’s

Insulation tests


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o between phase to phase

o phase to neutral

o phase to ground

Correct phasing for all circuits

Tightness of all connections

Measure the load for each circuit and confirm that each AC MCB

operates correctly

Verify the open and trip alarms for all MCB’s

No DC presence

Continuity between ground and earth (avoid floating neutral)

9.3.2 Substation DC systems

9.3.2.1 DC distribution panels

The following tests shall be applied to all panels being part of the substation

common DC systems:

Check against the design the correct type and rating for all DC

MCB’s

Insulation tests

o between positive and negative

o positive to ground

o negative to ground

Correct polarity for all circuits and MCB’s

Tightness of all connections

Measure the load for each circuit and confirm that each DC MCB

operates correctly

Verify the open and trip alarms for all DC MCB’s

Check there is no AC presence

Phase-ground voltage

9.3.2.2 Batteries and chargers

The Station Batteries shall be examined to confirm the following:

No physical damage

Electrolyte levels are correct and no leaks observed.

Positive and Negative conductors installed and rated as specified.

Appropriate ventilation provided in battery room

Lamps, fittings and sensors appropriately rated for application

Availability and access to First Aid /safety equipment

The following tests shall be performed on all substation batteries:

Following the manufacturers guidelines fully charge the batteries and

record the Specific Gravity and Cell voltage of each cell.


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Conduct discharge test according to manufactures guidelines

Record specific gravity and cell voltage measurements at prescribed

intervals during the discharge cycle.

The battery chargers shall be examined to confirm the following:

No physical damage

Installed, connected and earthed as per manufacturers instruction

Verify appropriate rating of MCB’s

The following tests shall be performed on all substation battery chargers:

Verify Charger Changeover Facilities & Fusing

Verify charger set point voltages

Verify correct operation of charger control and alarm functions

Verify battery supervision earth fault sensitivity levels

Verify battery supervision under & over voltage alarm levels





serviceability of any component in the AC systems, DC systems or Station

Battery, the component shall be replaced.

9.4 Site Data

Record all necessary charger, battery supervision cabinet and

battery data as per relevant test result forms.

9.5 Final Checks


All connections are tight



All labelling, and warning notices have been erected.

All safety notices have been applied




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10 Feeder Impedance Protection Commissioning

Procedure

10.1 General

10.1.1 Scope

This document describes the commissioning procedure to be performed on

all feeder impedance protection relays on the transmission system.

The tests described in this document should be performed prior to

energisation and when applicable, during subsequent preventive


performed after the replacement of any equipment\component forming part

of the feeder differential protection scheme.


corrective maintenance tasks or protection investigations after a system

disturbance.

10.1.2 Object


that ensure the integrity and correct operation of all feeder impedance

relays and schemes.


Relevant commissioning spreadsheet.

Automated test file for the particular application.

IEC 60255.

Final ‘in-service’ setting/configuration file(s) issued by relevant setting

authority.


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10.2 Procedure

10.2.1 Feeder Impedance Protection Tests

The protection relay shall be subjected to a comprehensive series of tests to

prove the correct performance of that relay in terms of the integrity of the

device and the operational performance intended by the setting authority.

The protection tests are to be carried out with the ‘in-service’

configuration\settings\marshalling applied.

All enabled protection functions will be tested. This includes

customised logic\protection functionality associated with non-

standard Special Protection Schemes.

Protection relay tests will be carried out by secondary injection using

computer driven power system simulator test kits.

Protection test equipment will have a valid up to date calibration

certificate.

All test routines, test results and site data shall be recorded on the

relevant test results database.



serviceability of any component in the relay, the component shall be

replaced.

10.2.2 Site Data

Record all relevant relay data as per relevant test result forms.

Confirm that the relay is suitable for the application.


The protection equipment shall be examined to confirm the following:

No physical damage.

No ingress of moisture, dust or any other particle which could impair

the performance of the equipment.

No damage to keypad or HMI

No signs of contact erosion due to arcing or corrosion

No signs of excessive heating

Nameplate ratings as per appropriate application and substation

single line diagram and nominal voltage and current values.

All wiring and connection shall be verified for correctness and

tightness

Labelling is appropriate to the application.


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10.2.4 External Wiring Tests

All external wiring associated with the protection equipment will be proven in

accordance with standard procedures.

These circuits include;

CT and VT secondary circuits

DC circuits

o Supply circuits

o Logic circuits

o Tripping circuits

o Alarm circuits

10.2.5 Protection Relay Tests

The protection relay tests will be carried out to ensure that all

settings\configuration etc. have been applied correctly to the relay and that

the functions are mutually compatible. All enabled functions shall be fully

tested.

Secondary current injection tests will be carried out using Power System

Simulator test kits with the appropriate test plan to prove the following;

Relay Pick up for all fault loops

Timing for all zones and other functions

Impedance zone plots

Impedance teleprotection functions

Earth fault protection functions

o Pickup level and directionality/polarization

o Blocking functions

o Tele-protection functions

Auto-recloser functions

o Single/three phase operation with dead time adjustment

o Internal/external blocking functions

Integrated/External Circuit Breaker Failure Protection functions

Overcurrent functions

o SOTF Function

o Emergency/Backup Functions

o Directional Functions

Voltage/Frequency functions

Relay alarms


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These tests shall be carried out on all relay elements in accordance with the

appropriate approved test plan and must comply with the pass\fail criteria

identified in the test plan.

End to end testing (relay to relay) using multiple secondary injection test kits

will be carried out applying multiple synchronous faults to the protection at

both ends of the feeder with the aid of GPS timing.

10.2.6 Relay Functional Tests

In schemes where more than one relay per bay is installed, all signals

exchanged between these relays must be proven functionally, by secondary

injection using Power System Simulator test kits.

As applicable, confirm the following relay functions as per appropriate

substation design schematic diagrams.

Protection relay circuit breaker tripping and, if applicable, Auto-

Reclosing tests and cross-blocking

Circuit Breaker Failure Starts

All binary inputs operated correctly for all enabled functions from

source to relay

All binary outputs operated correctly for all enabled functions from

relay to destination

All LED’s operated correctly for all enabled functions

All relay functions provide the correct local and remote indications

Power System Simulator test kits shall be used for all the above

tests.

10.2.7 Final Tests

On completion of the impedance relay tests the following must be

confirmed;

Correct Settings applied to relay

All CT terminals and shorting \isolating facilities are normal

Protection relay test facilities are normal

All relay alarms\flags\internal buffers are clear

If applicable, correct date\time is set on relay

All LED’s have been labelled in accordance with the assigned

function(s)

As commissioned set file was uploaded from the protection relay

Test report has been completed; all tests assessed and signed off.


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10.2.8 On Load Tests

Immediately after load is applied to the feeder, an on load test must be

carried out on the relay to verify the correct power flow on the feeder.

Measured values will be compared between the line ends.

This test must be carried out in accordance with the relay manufacturer’s

recommendations. These recommendations will outline minimum load

levels. The results of the on load test result shall be recorded in the

appropriate commissioning report.


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11 Feeder Differential Protection Commissioning Procedure

11.1 General

11.1.1 Scope


all feeder differential protection relays on the transmission system.








disturbance.

11.1.2 Object


that ensure the integrity and correct operation of all feeder differential relays

and schemes.


Automated test file for the particular application

Relevant commissioning spreadsheet

IEC 60255


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11.2 Procedure

11.2.1 Feeder Differential Protection Tests












certificate.






replaced.

Generally if there is a hardware fault in the relay, it will manifest itself in a

recognisable pattern of test result failures. This pattern can be then easily

diagnosed as a faulty component resulting in a relay failure and,

consequently, replacement of the unit.

11.2.2 Site Data





No physical damage.







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tightness






CT and VT(if applicable) secondary circuits

DC circuits

o Supply circuits

o Logic circuits

o Tripping circuits

o Alarm circuits





tested.




Timing

Differential Slope\Characteristic


Non Differential protection functions as set

Auto-recloser Functions and dead time adjustment

Internal/External blocking functions

Relay alarms




A relay slope\characteristic test will be carried out using GPS synchronised

power system simulation test kits. These test kits will simulate stable and

faulted system conditions on both differential relays at either end of the

feeder simultaneously.


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exchanged between these relays must be proven functionally, by secondary

injection using Power System Simulator test kits.



Protection relay circuit breaker tripping and, if applicable, Auto-

Reclosing tests and cross-blocking



source to relay






tests.

11.2.7 Final Tests

On completion of the differential relay tests the following must be confirmed;







function(s)





carried out on the relay to verify the correct summation of all CT’s

contributing to the feeder differential scheme using system load.


recommendations. These recommendations will outline minimum load levels

and acceptable differential current tolerances. The results of the on load

test result shall be recorded in the appropriate commissioning report.


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12 Feeder Overcurrent Protection Commissioning Procedure

12.1 General

12.1.1 Scope


all feeder/bay overcurrent protection relays on the transmission system.





of the overcurrent protection scheme.



disturbance.

12.1.2 Object


that ensure the integrity and correct operation of all feeder/bay overcurrent

relays and schemes.




IEC 60255

12.2 Procedure

12.2.1 Feeder/Bay Overcurrent Protection Tests





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certificate.






replaced.

12.2.2 Site Data





No physical damage.









tightness






CT and VT(if applicable) secondary circuits


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DC circuits

o Supply circuits

o Logic circuits

o Tripping circuits

o Alarm circuits





tested.



All enable parameter sets shall be tested.


Timing

All overcurrent operating characteristics

Directionality of the overcurrent characteristic if applicable



Relay alarms






exchanged between these relays – if applicable, must be proven

functionally, by secondary injection using Power System Simulator test kits.



Protection relay circuit breaker tripping



source to relay






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Power System Simulator test kits shall be used for all the above tests.

12.2.7 Final Tests








function(s)


Test sheet has been completed, all tests assessed and signed off.



carried out on the relay to verify the correct values displayed by the relay.


recommendations. The results of the on load test result shall be recorded in

the appropriate commissioning report.


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13 Transformer Differential Protection Commissioning Procedure

13.1 General

13.1.1 Scope


all transformer differential protection relays on the transmission system.








disturbance.

13.1.2 Object


that ensure the integrity and correct operation of all transformer differential

relays and schemes.


Transformer manufacturer manual


Relevant spreadsheet

IEC 60255


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13.2.1 Transformer Differential Protection Tests






All test routines, test results and site data shall be recorded on the relevant

test results database.




replaced.

13.2.2 Site Data





No physical damage.









tightness



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CT secondary circuits

DC circuits

o Supply circuits

o Logic circuits

o Tripping circuits

o Alarm circuits




the functions are mutually compatible. All enabled functions and parameter

sets shall be fully tested.




Timing



Non Differential protection functions as set


Relay alarms







Protection relay circuit breaker tripping



source to relay


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tests.

13.2.7 Final Tests








function(s)


Test report has been completed, all tests assessed and signed off.


Immediately after load is applied to the transformer, an on load test must be


contributing to the transformer differential scheme using system load.






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14 Transformer Non Current Protection Commissioning Procedure

14.1 General

14.1.1 Scope


all transformer non-current protection devices/relays on the transmission

system.





of the non-current protection scheme.



disturbance.

14.1.2 Object


that ensure the integrity and correct operation of all transformer non-current

based schemes.


Transformer manufacturer manual


Relevant spreadsheet

IEC 60255

14.2 Procedure

Non current based transformer protections refer but not limited to:

Overfluxing protection

Temperature protection

Gas/Bucholz protection


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14.2.1 Overfluxing Protection

Transformer overfluxing is a preventative protection and protects the

transformer against overheating caused by changes in the system voltage

and/or frequency.










the functions are mutually compatible. All enabled functions and parameter

sets shall be fully tested.




VT secondary circuits

DC circuits

o Supply circuits

o Logic circuits

o Tripping circuits

o Alarm circuits

Secondary voltage injection tests will be carried out using Power System



Timing

Operating Characteristics



Relay alarms

Relay functional tests shall be carried out to prove:

Circuit Breaker tripping

Circuit Breaker Failure starts


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source to relay












function(s)


14.2.2 Temperature protection

Power transformers are equipped with temperature devices which monitor

the transformer windings and oil temperature.

The temperature devices will have to be calibrated as per transformer

manufacturer or client specific requirements. A temperature calibrator with a

calibration certificate up to date shall be used.

The temperature devices shall be tested for the following functions:

Oil temperature alarm

Winding(s) temperature alarm

Oil pumps start/stop

Transformer fans start/stop

Oil temperature trip

Winding(s) temperature trip

As applicable, confirm the following functions as per appropriate substation

design schematic diagrams:

Circuit Breaker tripping

All alarms and trips provide the correct local and remote indication.

14.2.3 Gas/Bucholz protection

Transmission transformers are fitted usually with at least one Bucholz relay

on the main tank. From case to case, depending on the type of the power


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transformer, we may find Bucholz relays on the on load tap changer and

transformer bushings or cable boxes.

All these relays shall be subject to test. The test shall be carried out after the

transformer was fully filled with oil. The test is done using air pumped into

each relay in turn.


substation design schematics:

Circuit breaker tripping

Circuit breaker failure starts

Bucholz Gas alarm

All relays provide the correct local and remote indications

14.2.4 Final Tests

On completion the following must be confirmed:

All trips and alarms have been cleared.



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15 Synchronising Commissioning Procedure

15.1 General

15.1.1 Scope


all synchronising schemes on the transmission system.





of the synchronising or voltage selection scheme.



disturbance.

15.1.2 Object


that ensure the integrity and correct operation of all synchronising and

voltage selection schemes.


Bay controller manufacturer manual if applicable

Voltage selection scheme logic diagram and schematics


Final ‘in-service’ setting/configuration file issued by the relevant setting

authority

15.2 Procedure

Commissioning synchronising schemes involves commissioning a voltage

selection scheme as a prerequisite. Therefore this procedure will list the

minimum steps required for voltage selection scheme commissioning first

and synchronising after.


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15.2.1 Voltage selection scheme tests

Testing the voltage selection scheme is a two steps process. First stage is

commissioning of the voltage selection scheme for each bay individually. In

this stage the following test will be carried out:

Correct bay image into voltage selection scheme for all feeding

arrangements

Secondary injection for VT circuits

Reference and Incoming voltage presence at the synchronising

device input

Once each bay has been successfully tested and integrated into the station

voltage selection scheme, overall scheme shall be tested to prove that the

scheme performs as per requirements for all busbar and feeding

arrangements.

Special attention must be taken not to backfeed the VT during these tests.

15.2.2 Synchronising scheme tests

The following tests shall be performed on each bay:

Check the DC supplies for the scheme.

Prove the direct and synch close command circuits into the

controller.

Verify the controller output circuits for closing the circuit breaker

Local / Remote operation circuits.

Using a Power System Simulator test kit, test the operation of the

controller in conjunction with settings issued by the system

controller, covering at least the following instances:

o Voltage difference

o Phase difference

o Frequency difference

When each of the above condition is within the settings thresholds a

successful close command shall be issued locally and from the

relevant control centre to prove the correct operation



serviceability of any component of the scheme, the component shall be

replaced.


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15.2.3 Site Data

Record all relevant data as per relevant test result forms.

Confirm that the relay/bay controller is suitable for the application.


The bay controller and synchronising device shall be examined to confirm the

following:

No physical damage.









tightness






VT secondary circuits

DC circuits

o Supply circuits

o Logic circuits

o Control circuits

o Alarm circuits

15.3 Final Tests

On completion of the synchronising tests the following must be confirmed;





function(s)


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16 Station bus zone / circuit breaker failure protection commissioning procedure

16.1 General

16.1.1 Scope


all bus zone / circuit breaker protection schemes on the transmission

system.








disturbance.

16.1.2 Object


that ensure the integrity and correct operation of all bus zone / circuit

breaker failure protection schemes.


Automated test file for the particular application.

Relevant spreadsheet.

IEC 60255.

16.2 Procedure

The process of commissioning these types of schemes is a two stage

process. Stage one involves the commissioning of the bay wiring, and stage

two involves testing the per bay protection and overall scheme functional

tests.


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16.2.1 Commissioning of the bay wiring into the scheme

This process shall be followed for every bay within the substation, and

requires outages on all bays during this phase in order to commission the

wiring.

No testing of the relays(s) should be carried out during this phase.

The following tests must be carried out during this phase:

Inspection of the bus zone protection cabinet

Confirmation that the cabinet internal wiring is complete and correct

Confirmation that the design is correct

Secondary injection of CT circuits from the CT to the bay units

Verification of the bus image including the auxiliary contact type

Verification of CBF start circuits

Verification of trip circuits and trip isolation integrity

Verification of remote transmit circuits

Verification of DC supplies

Remote permissive\ AR blocking GPS tests

All bays must have phase one completed in order to proceed to the next

phase.

16.2.2 Scheme testing



Relay Pick-up for all fault loops for bus zone and CBF functions

Timing test for bus zone and CBF functions


Circuit Breaker Failure Protection functions

Non current starts for circuit breaker failure protection


Relay alarms

The above tests shall be run for every bay being part of the bus zone circuit

breaker protection scheme.








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replaced.

16.2.3 Site Data





No physical damage.









tightness


16.2.5 Overall scheme Functional Tests



CBF function tripping selectivity for all busbar arrangements

Bus Zone tripping selectivity for all busbar arrangements

Scheme blind spots




16.2.6 Final Tests








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function(s)




Immediately after load is applied to the busbar, an on load test must be


contributing to the busbar differential scheme using system load.






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17 Station SCADA systems, remote control and indications

17.1 General

17.1.1 Scope

This document lays out a procedure for commissioning of stations where a

numerical Station Control System is installed.

17.1.2 Object


that ensure the integrity and correct operation of the Station Control System.




17.2 Procedure

17.2.1 Prerequisites

The Station Control System shall be installed, pre-commissioned by

Automation & Telecom and ready for service. The local and Control

center(s) alarm database ready and functional. All controls, position

indications, alarms and measurands tested (simulated) and fully functional

as part of the pre-commissioning process.

17.2.2 Site Data


Confirm that the bay controller is suitable for the application.


The SCS equipment shall be examined to confirm the following:

No physical damage.


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tightness



All external wiring associated with the bay controller will be proven in



CT and VT secondary circuits

DC circuits

o Supply circuits

o Logic circuits

o Control circuits

o Position indication circuits

o Alarm circuits

17.2.5 Commissioning Tests

The commissioning tests will be carried out to ensure that all controls,

alarms and measurands work in concordance with design and the

manufacturer specifications.


Simulator test kits with the appropriate test plan to prove the correct local

and remote measurands indication for each bay.

As applicable, confirm the following functions as per appropriate substation

design schematic diagrams.

All control circuits connected to the bay control unit

All position indication circuits for the switchgear

All switchgear related alarms

All binary inputs operated correctly from source to bay control unit

All binary outputs operated correctly from bay control unit to

destination



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All controls, position indication and alarms have been tested locally

and remotely to the control center(s)

17.3 Final Tests

On completion of the above tests the following must be confirmed;

If applicable, correct date\time is set on the system


function(s)

Test report has been completed, all tests assessed and signed off.

17.4 On Load Tests


carried out to verify the correct power indication on the feeder. Measured

values will be compared between local indication and control center(s)


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HV Lines


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18 HV Lines

18.1 Line Corridor

18.1.1 Scope

This document describes the test procedures to be performed on all new HV

overhead power line corridors before the circuit is connected to the

transmission system. The tests described in this document should be

performed during the commissioning stage of a new build project and,

where applicable, during subsequent corrective maintenance. The


replacement or resagging of any section of overhead line conductor during

an uprate or refurbishment of an existing overhead line.

18.1.2 Objective

The objective of this document is to provide a minimum set of test

procedures that verify that a newly constructed HV overhead line maintains

minimum electrical safety clearances as specified within the project safety

file and/or within the current revision of EN 50341-1 and Irish National

Normative Aspects (NNAs) EN 50341-3-11.


Current revision of EN 50341-1 and Irish NNAs EN 50341-3-11.

18.1.4 Procedure

18.1.4.1 Safety File Data The appointed project designer must provide the commissioner with all

relevant design information from the project safety file prior to any

commissioning work proceeding.

The minimum information a commissioner requires is:

Line Design Sheet detailing structure numbering, type/grade and

Height;

Line Profiles detailing conductor sag and line crossings/conflicts;

Line Route Map detailing structure locations;

Conductor sag charts or tables.

18.1.4.2 Ground Clearance Check ground clearance complies with clearances set out within EN

50341-1 and Irish NNA EN 50341-3-11.


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18.1.4.3 Timber

Check all timber along the line corridor adheres to clearances set out

within EN 50341-1 and Irish NNA EN 50341-3-11.

18.1.4.4 Line Crossings

Check all telecommunication lines, electricity lines, roads, railways and

navigable waterways maintain clearances set out within EN 50341-1 and

Irish NNA EN 50341-3-11.

18.1.4.5 Building Conflicts

Check all buildings maintain clearances set out within EN 50341-1 and

Irish NNA EN 50341-3-11.


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18.2 Lattice Steel Tower

18.2.1 Scope

This document describes the test procedures to be performed on all new

lattice steel towers before overhead line conductors can be strung from or

connected to each structure. The tests described in this document should

be performed during the commissioning stage of a new build project and,

where applicable, during subsequent corrective maintenance where

significant sections or the entire structure may be replaced.

18.2.2 Objective


procedures that verify a newly constructed lattice steel tower is built as per

design specified within the project safety file.


Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.

18.2.4 Procedure

18.2.4.1 Safety File Data

The appointed project designer must provide the commissioner with all




Line Design Sheet detailing structure numbering, type/grade, tower

orientation and height;


Tower foundation drawing(s) and any specific design requirements

on tower foundation material and/or construction method;

Tower structure drawing(s) and any specific erection specifications;

Tower dimension tolerances.

18.2.4.2 Foundation Supervision

The foundation construction must be supervised to verify that the ground

conditions suit the foundation type specified, the correct material is used

and the correct construction method adopted as specified in the project

safety file. The commissioner may appoint a competent civil engineer to

carry out this supervisory role on their behalf.


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18.2.4.3 Tower Dimensions Check

When the tower foundation and base is constructed the tower dimensions

must be checked to verify they meet the tower tolerance specified within

the project safety file. Tolerance conformance must be checked for relative

tower leg levels, diagonal dimensions, face dimensions and overall tower

orientation. The tower dimensions must be verified as meeting the relevant

design tolerances prior to conductor stringing occurring.

18.2.4.4 Concrete Cube Sample Tests

The commissioner must verify that all cube samples taken during the

foundation construction stage meet the minimum strength requirements

specified within the project safety file. The concrete cube samples must be

verified as meeting the minimum strength requirements specified within the

project safety file prior to conductor stringing occurring. The commissioner

may appoint a competent civil engineer to carry out this supervisory role on

their behalf.

18.2.4.5 Visual Inspection

When the tower is fully erected the commissioner must:

Inspect all bars/members, plates, bolts and nuts to verify that they

are installed as per design;

Inspect all steelwork to ensure there are no damaged bars/members;

Inspect all steelwork galvanising to verify that it meets design

standard specified in the project safety file;

Verify that shear block is installed as per design;

Verify that the correct Name Plate and Danger Notices are installed

as per design.


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18.3 Steel Monopole

18.3.1 Scope


steel monopoles before overhead line conductors can be strung from or

connected to each structure. The tests described in this document should

be performed during the commissioning stage of a new build project.

18.3.2 Objective


procedures that verify a newly constructed steel monopoles is built as per




18.3.4 Procedure






Line Design Sheet detailing structure numbering, type/grade,

monopole orientation and height;


Monopole foundation drawing(s) and any specific design

requirements on monopole foundation material and/or construction

method;

Monopole structure drawing(s) and any specific erection

specifications;

Monopole orientation tolerances.








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18.3.4.3 Monopole Orientation Check

When the steel monopole is fully constructed the monopole orientation

must be checked to verify that it meets the orientation specified within the

project safety file. The monopole orientation must be verified as meeting

the design specified prior to conductor stringing occurring.

18.3.4.4 Concrete Cube Sample Tests

The commissioner must verify that all cube samples taken during the

foundation construction stage meet the minimum strength requirements

specified within the project safety file. The concrete cube samples must be

verified as meeting the minimum strength requirements specified within the

project safety file prior to conductor stringing occurring. The commissioner

may appoint a competent civil engineer to carry out this supervisory role on

their behalf.


When the monopole is fully erected the commissioner must:

Inspect all steelwork to ensure there is no damage along the

monopole structure or to any crossarms;



Inspect the monopole shear block/base to verify that it is installed as

per design;


as per design.

110 kV Braced Angle Woodpole


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18.4 110 kV Braced Angle Woodpole

18.4.1 Scope


110 kV braced angle woodpoles before overhead line conductors can be

strung from each structure. The tests described in this document should be

performed during the commissioning stage of a new build project and,

where applicable, during subsequent corrective maintenance.

18.4.2 Objective


procedures that verify a newly constructed 110 kV braced angle woodpole is

built as per design specified within the project safety file.



18.4.4 Procedure



Line Design Sheet detailing structure numbering, type/grade, braced

woodpole orientation and height;


Braced Woodpole foundation drawing(s) and any specific design

requirements on foundation material and/or construction method;

Braced Woodpole structure drawing(s) and any specific erection

specifications.








When the braced woodpole is fully erected the commissioner must:





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Inspect all woodpoles to verify that they meet the design standard

specified within the project safety file;


as per design.

110 kV Intermediate Woodpole


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18.5 110 kV Intermediate Woodpole

18.5.1 Scope


110 kV intermediate woodpoles before the involved can be energised. The

tests described in this document should be performed during the

commissioning stage of a new build project and, where applicable, during

subsequent corrective maintenance.

18.5.2 Objective


procedures that verify a newly constructed 110 kV intermediate woodpole is

built as per design specified within the project safety file.



18.5.4 Procedure



Line Design Sheet detailing structure numbering, type/grade and

height;


Woodpole foundation drawing(s), if any, and any specific design

requirements on foundation material and/or construction method;

Woodpole structure drawing(s) and any specific erection

specifications.


When the woodpole is fully erected the commissioner must:

Inspect all woodpoles to verify that they meet the design standard


Inspect all pole bolts and nuts to verify they are installed as per

design;

Inspect crossarm to verify it is installed and positioned as per design;

Inspect all earthwire brackets, if present, to verify they are installed

and orientated as per design;

Inspect all stays, if present, to verify they are installed as per design;


as per design.


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18.6 Conductor & Hardware

18.6.1 Scope


overhead conductors before the new circuit is energised. The tests

described in this document should be performed during the commissioning

stage of a new build project and, where applicable, during subsequent

corrective maintenance. The appropriate tests from this document shall also

be performed after the replacement or resagging of any section of overhead

line conductor during an uprate or refurbishment of an existing overhead

circuit.

18.6.2 Objective


procedures that verify that new overhead line conductor is strung as per




18.6.4 Procedure






Line Design Sheet detailing conductor straights, span lengths and

conductor details;

Line Profiles detailing conductor sag;

Line Route Map detailing line route;

Conductor sag charts or tables;

Conductor hardware drawing(s).


When the conductor is strung the commissioner must:

Inspect the conductor to verify it is free from damage on outer

strands and there is no indication of birdcaging;


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Inspect all dampers, midspan joints, deadend joints, clamps and

spacers (if present) to verify that they meet the design standard

specified within the project safety file.

18.6.4.3 Sag Check

Check conductor sag to verify that it meets the sag limits specified within the project safety file.

18.7 Insulator & Hardware

18.7.1 Scope


insulators and hardware before the circuit involved is energised. The tests

described in this document should be performed during the commissioning

stage of a new build project and, where applicable, during subsequent

corrective maintenance.

18.7.2 Objective


procedures that verify newly erected insulators and insulator hardware are

installed as per design specified within the project safety file.



18.7.4 Procedure






Line Design Sheet detailing insulator arrangement at each structure;


Insulator assembly drawing(s).


When insulators assemblies are erected the commissioner must:

Inspect each insulator assembly to verify it is installed as per design

specified with the project safety file.


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18.8 Jumpers

18.8.1 Scope


overhead line jumper arrangements before they form part of an energised

circuit. The tests described in this document should be performed during the



18.8.2 Objective


procedures that verify that a newly constructed jumper arrangement is




18.8.4 Procedure






Line Design Sheet detailing structure locations;


Jumper assembly drawing(s).





Inspect the overall jumper assembly to verify that it meets the design


Inspect all jumper terminals, clamps, jumper weights and auxiliary

insulator chains (if present) to verify that they meet the design

standard specified within the project safety file.


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18.8.4.3 Jumper Clearance Check

Inspect the overall jumper assembly to verify that it meets the clearances

specified within the project safety file. If jumper clearance requirements are

not specified within the project safety file, the commissioner must verify that

the jumper clearances comply with clearances specified within the current

revision of EN 50341-1 and Irish NNA EN 50341-3-11.

18.9 Station lead-in connection

18.9.1 Scope


station lead-in connections before they form part of an energised circuit. The




18.9.2 Objective


procedures that verify that a newly constructed lead-in connection is




18.9.4 Procedure






Station lead-in arrangement drawing;

Station lead-in conductor type.





Inspect the overall lead-in arrangement to verify that it meets the

design specified within the project safety file;


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Inspect all deadend joints, clamps and spacers (if present) to verify

that they meet the design standard specified within the project safety

file.

18.10 Station Busbar

18.10.1 Scope


station busbars before they are connected to the transmission system. The



subsequent corrective maintenance. The appropriate tests from this

document shall also be performed after the replacement or resagging of any

section of station busbar during an uprate or refurbishment project.

18.10.2 Objective


procedures that verify a newly constructed station busbar is built as per the




18.10.4 Procedure






Station busbar support drawing(s);

Station busbar phase design/type.


When each busbar support is fully erected the commissioner must:







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Verify that shear blocks are installed as per design;


as per design.

When busbar phases are strung/installed the commissioner must:

Inspect the busbar to verify that each phase is installed as per the



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19 HV Cables

19.1 Visual Inspection

19.1.1 Scope

This document describes the Visual Inspections that must be performed on

all new HV Cables before the circuit is connected to the transmission

network. The tests described in this document should be performed during

the commissioning stage of a new build project and, where applicable,

during subsequent corrective maintenance where some sections of the

cable circuit or the entire cable circuit may be replaced or repaired.

19.1.2 Objective

The objective of this document is to provide a minimum set of visual

inspections that verify a newly constructed HV Cable Circuit meets the

design requirements set out within the project safety file.


110kV: Current Revision of IEC 60840



19.1.4 Procedure

19.1.4.1 Safety File Data The appointed project designer must provide the commissioner with all relevant design information from the project safety file. The minimum information a commissioner requires is:

Cable Route Map, showing all joint bay locations and all termination

locations.

Bonding Diagram, showing phasing of circuit, termination types,

cable type, bonding design, sheath interruptions.

19.1.4.2 Visual Inspection Procedure HV Cable Circuit to be Visually Inspected in accordance with relevant IEC

standard, depending on voltage, as referenced in 7.1.3.

All Terminations, Link Boxes/Sheath Interruptions, Bonding Arrangements

to be visually inspected during commissioning works.

Cable Route to be visually inspected during commissioning works to

ensure no third party damage present.


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19.2 Sheath Test

19.2.1 Scope

This document describes the Sheath Tests that must be performed on all

new HV Cables before the circuit is connected to the transmission network.

The tests described in this document should be performed during the


subsequent corrective maintenance where some sections of the cable circuit

or the entire cable circuit may be replaced or repaired.

19.2.2 Objective


procedures that verify that the sheath of a newly constructed HV Cable

Circuit meets the design standard specified within the project safety file.


Current Revision of IEC 60229



19.2.4 Procedure



locations.



19.2.4.2 Sheath Test Procedure HV Cable Circuit to be Sheath Tested in accordance with relevant IEC

standard, depending on voltage, as referenced in 7.1.3.

For 110kV Circuits Section 14.1 of IEC 60840 applies.

For 220kV & 400kV Section 15.1 of IEC 62067 applies.

Both these test standards are used in conjunction with IEC 60229.


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19.3 220 kV & 400 kV HV AC Core Test

19.3.1 Scope

This document describes the HV AC Core Test that must be performed on

all new 220kV & 400kV HV Cables, where applicable, before the circuit is

connected to the transmission network. The tests described in this

document should be performed during the commissioning stage of a new

build project and, where applicable, during subsequent corrective

maintenance where some sections of the cable circuit or the entire cable

circuit may be replaced or repaired.

19.3.2 Objective

The objective of this document is to provide a minimum set of test standards

that verify the core of a newly constructed 220 kV or 400 kV HV Cable

Circuit meets the design standard specified within the project safety file.


Current Revision of IEC 62067.

19.3.4 Procedure



locations.



Cable Manufacturers Specification.

19.3.4.2 HV AC Core Test Procedure HVAC Core Test on HV Cable Circuit to be carried out in accordance with

Section 15.2 of IEC 62067.


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19.4 Oil Filled Impregnation Test

19.4.1 Scope

This document describes the Oil Impregnation Test that must be performed

on all new Oil Filled HV Cables, where applicable, before the circuit is






19.4.2 Objective


that verify that the paper insulation on a newly constructed Oil Filled HV

Cable Circuit is immersed in oil to the design standard specified within the

project safety file.


Engineering Recommendation C84

HV Cable Manufacturer’s Operation & Maintenance Manuals

19.4.4 Procedure



locations.

Cable Profile, showing all joint bay locations, all termination locations

and all oil tank locations.



Cable Manufacturing Specification, including volume of oil per

kilometre.

Accessories (termination, joints, tanks) Manufacturers Specification,

including volume of oil per accessory.

19.4.4.2 Oil Filled Impregnation Test Procedure Oil Filled Impregnation Test on an Oil-Filled HV Cable Circuit to be carried

out in accordance with Engineering Recommendation C84.


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19.5 Oil Filled Cable Flow Test

19.5.1 Scope

This document describes the Cable Flow Test that must be performed on

all new Oil-Filled HV Cables, where applicable, before the circuit is






19.5.2 Objective


that verify a newly constructed Oil-Filled HV Cable Circuit has adequate oil

insulation along the entire cable route.


Engineering Recommendation C84

Cable Manufacturer’s Operation & Maintenance Manuals

19.5.4 Procedure



locations.

Cable Profile, showing all joint bay locations, all termination locations

and all oil tank locations.



Cable Manufacturing Specification, including volume of oil per

kilometre.

Accessories (termination, joints, tanks) Manufacturers Specification,

including volume of oil per accessory.


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19.5.4.2 Oil Filled Flow Test Procedure Oil Filled Flow Test on an Oil-Filled HV Cable Circuit to be carried out in

accordance with Engineering Recommendation C84.

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