EirGrid Commissioning Procedures Rev 0
-
Upload
scott-newton -
Category
Documents
-
view
70 -
download
4
description
Transcript of 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
DP-040-006
3 of 91
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
DP-040-006
5 of 91
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
6 of 91
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
3.2 Commissioning Tests 18
4 Disconnect Commissioning Procedure 21
4.1 General 21
4.2 Commissioning Tests 21
4.3 Disconnect tests 21
5 Surge Arrestor Commissioning Procedure 24
5.1 General 24
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
7 of 91
5.2 Commissioning Tests 24
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
9.3 Commissioning Tests 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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
8 of 91
13 Transformer Differential Protection Commissioning Procedure
51
13.1 General 51
13.2 Commissioning Tests 52
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
9 of 91
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
10 of 91
PRIMARY PLANT AND CIRCUITS
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
11 of 91
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
12 of 91
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
13 of 91
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
14 of 91
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
15 of 91
2 Circuit breaker Commissioning Procedure
2.1 General
2.1.1 Scope
This document describes the test procedure to be performed on all high
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.
These tests may also be used in conjunction with other specialised tests
recommended by circuit breaker manufacturer for corrective maintenance
tasks and condition assessment.
2.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all circuit breakers.
2.1.3 Reference Documents
Circuit Breaker manufacturer reference manual
Circuit Breaker Commissioning Test Sheet
IEC 62271-100
2.2 Commissioning Tests
2.2.1 Circuit breaker Tests
The following tests shall be performed on the equipment that comprises the
circuit breaker as per section 2.1.1
All test results and site data shall be recorded on the relevant
commissioning test sheet.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
16 of 91
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
Check clearances to be in accordance with Safety Standards/ Rules or IEC
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.
WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO
WORKING ON PRIMARY EQUIPMENT.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
17 of 91
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
On completion of testing confirm the following:
Test sheet has been completed, all tests assessed and signed off
HV connections torqued
All test equipment has been removed.
All labelling, and warning notices have been applied
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
18 of 91
3 Instrument Transformer Commissioning Procedure
3.1 General
3.1.1 Scope
This document describes the test procedure to be performed on all high
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
maintenance. The appropriate tests from this document shall also be
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
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all instrument transformers.
3.1.3 Reference Documents
Instrument transformer manufacturer reference manual
Instrument transformer Commissioning Test Sheet
IEC 60044
3.2 Commissioning Tests
3.2.1 Instrument Transformer Tests
The following tests shall be performed on the equipment that comprises the
instrument transformer as per section 3.1.1
All test results and site data shall be recorded on the relevant
commissioning test sheet form.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
19 of 91
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 that nameplate rating corresponds to Single Line Diagram.
Confirm orientation is as per Single Line Diagram
3.2.3 Visual Inspection
The instrument transformers shall be examined to confirm the following:
No physical damage.
Oil levels are correct and no leaks present.
Earthing requirements are as specified.
3.2.4 Clearances
Check clearances to be in accordance with Safety Standards/ Rules or IEC
60071
3.2.5 Insulation Resistance Tests (Megger)
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
WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO
WORKING ON PRIMARY EQUIPMENT.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
20 of 91
3.2.7 Voltage Transformers
Verify polarity.
Verify turns ratio.
Conduct connected secondary wiring integrity, polarity and functionality checks
3.2.8 Final Checks
On completion of testing confirm the following:
Secondary wiring connections are tight
HV connections torqued
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
21 of 91
4 Disconnect Commissioning Procedure
4.1 General
4.1.1 Scope
This document describes the test procedure to be performed on all high
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
maintenance. The appropriate tests from this document shall also be
performed after the replacement of any equipment forming part of the
disconnect.
These tests may also be used in conjunction with other specialised tests
recommended by the disconnect manufacturer for corrective maintenance
tasks and condition assessment.
4.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all disconnects.
4.1.3 Reference Documents
Disconnect manufacturer reference manual
Disconnect Commissioning Test Sheet
IEC 62271-102
4.2 Commissioning Tests
4.3 Disconnect tests
The following tests shall be performed on the equipment that comprises the
disconnect as per section 4.1.1
All test results and site data shall be recorded on the relevant
commissioning test sheet.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
serviceability of any component in the disconnect, the component shall be
replaced.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
22 of 91
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.
4.3.2 Visual Inspection
The disconnects shall be examined to confirm the following:
No physical damage.
Earthing requirements are as specified.
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
4.3.4 Insulation Resistance Tests (Megger)
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
On completion of testing confirm the following:
WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO
WORKING ON PRIMARY EQUIPMENT.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
23 of 91
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.
HV connections torqued
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
24 of 91
5 Surge Arrestor Commissioning Procedure
5.1 General
5.1.1 Scope
This document describes the test procedure to be performed on all high
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
appropriate tests from this document shall also be performed after the
replacement of any equipment forming part of the surge arrestor.
These tests may also be used in conjunction with other specialised tests
recommended by the surge arrester manufacturer for corrective
maintenance tasks and condition assessment.
5.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity of the surge arrestor.
5.1.3 Reference Documents
Surge Arrestor Commissioning Test Sheet
IEC 60099 Part 1-8
5.2 Commissioning Tests
5.2.1 Surge Arrestor tests
The following tests shall be performed on the equipment that comprises the
Surge Arrestor as per section 5.1.1
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
serviceability of any component in the surge arrestor, the component shall
be replaced.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
25 of 91
5.2.2 Site Data
Record all necessary surge arrestor data as per relevant test result forms.
Confirm that nameplate rating corresponds to Single Line Diagram.
5.2.3 Visual Inspection
The surge arrestor shall be examined to confirm the following:
No physical damage.
Earthing requirements are as specified.
Counter reading recorded
5.2.4 Clearances
Check clearances to be in accordance with Safety Standards/ Rules or IEC
60071
5.2.5 Insulation Resistance Tests (Megger)
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
On completion of testing confirm the following:
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.
Primary connections torqued.
WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO
WORKING ON PRIMARY EQUIPMENT.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
26 of 91
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.
6.1.3 Reference Documents
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
27 of 91
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,
WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO
WORKING ON PRIMARY EQUIPMENT.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
28 of 91
phasing validation applies for every busbar, between busbars and across
coupler(s) for all possible combinations.
6.5 Final Checks
On completion of testing confirm the following:
Test sheets have been completed; all tests assessed and signed off.
All test equipment has been removed.
All labelling, and warning notices have been applied.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
29 of 91
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.
7.1.3 Reference Documents
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
30 of 91
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
WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO
WORKING ON PRIMARY EQUIPMENT.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
31 of 91
combination of inputs for which an output has not been specified
shall give no output.
7.5 Final Checks
On completion of testing confirm the following:
Test sheets have been completed; all tests assessed and signed off.
All labelling, and warning notices have been applied.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
32 of 91
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
The object of this document is to provide a minimum set of test procedures
that ensure the integrity of the substation earth grid.
8.1.3 Reference Documents
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
The following tests shall be performed on the equipment that comprises the
substation earth grid.
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
33 of 91
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
On completion of testing confirm the following:
Test sheets have been completed; all tests assessed and signed off.
All test equipment has been removed.
All labelling, and warning notices have been applied.
WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO
WORKING ON PRIMARY EQUIPMENT.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
34 of 91
SECONDARY CIRCUITS & PROTECTION
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
35 of 91
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.
These tests may also be used in conjunction with other specialised tests
recommended by the battery/charger manufacturer for corrective
maintenance tasks and condition assessment.
9.2.1 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all station AC and DC
common systems.
9.2.2 Reference Documents
AC commissioning Test Sheet
Station Battery Commissioning Test Sheet
Station Battery Charger and Battery Supervision Test Sheet
Battery and Charger manufacturer instructions
9.3 Commissioning Tests
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
36 of 91
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
37 of 91
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
All test results and site data shall be recorded on the relevant
commissioning test sheet.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
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
On completion of testing confirm the following:
All 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 erected.
All safety notices have been applied
WARNING: ESB SAFETY RULES MUST BE OBEYED PRIOR TO
WORKING ON PRIMARY EQUIPMENT.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
38 of 91
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
maintenance. The appropriate tests from this document shall also be
performed after the replacement of any equipment\component forming part
of the feeder differential protection scheme.
These tests may also be used in conjunction with other specialised tests for
corrective maintenance tasks or protection investigations after a system
disturbance.
10.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all feeder impedance
relays and schemes.
10.1.3 Reference Documents
Relevant commissioning spreadsheet.
Automated test file for the particular application.
IEC 60255.
Final ‘in-service’ setting/configuration file(s) issued by relevant setting
authority.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
39 of 91
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.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
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.
10.2.3 Visual Inspection
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
40 of 91
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
41 of 91
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
42 of 91
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
43 of 91
11 Feeder Differential Protection Commissioning Procedure
11.1 General
11.1.1 Scope
This document describes the commissioning procedure to be performed on
all feeder differential protection relays on the transmission system.
The tests described in this document should be performed prior to
energisation and when applicable, during subsequent preventive
maintenance. The appropriate tests from this document shall also be
performed after the replacement of any equipment\component forming part
of the feeder differential protection scheme.
These tests may also be used in conjunction with other specialised tests for
corrective maintenance tasks or protection investigations after a system
disturbance.
11.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all feeder differential relays
and schemes.
11.1.3 Reference Documents
Automated test file for the particular application
Relevant commissioning spreadsheet
IEC 60255
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
44 of 91
11.2 Procedure
11.2.1 Feeder Differential 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.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
serviceability of any component in the relay, the component shall be
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
Record all relevant relay data as per relevant test result forms.
Confirm that the relay is suitable for the application.
11.2.3 Visual Inspection
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
45 of 91
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.
11.2.4 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(if applicable) secondary circuits
DC circuits
o Supply circuits
o Logic circuits
o Tripping circuits
o Alarm circuits
11.2.5 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
Differential Slope\Characteristic
Integrated/External Circuit Breaker Failure Protection functions
Non Differential protection functions as set
Auto-recloser Functions and dead time adjustment
Internal/External blocking functions
Relay alarms
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.
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
46 of 91
11.2.6 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.
11.2.7 Final Tests
On completion of the differential 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.
11.2.8 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 summation of all CT’s
contributing to the feeder differential scheme using system load.
This test must be carried out in accordance with the relay manufacturer’s
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
47 of 91
12 Feeder Overcurrent Protection Commissioning Procedure
12.1 General
12.1.1 Scope
This document describes the commissioning procedure to be performed on
all feeder/bay overcurrent protection relays on the transmission system.
The tests described in this document should be performed prior to
energisation and when applicable, during subsequent preventive
maintenance. The appropriate tests from this document shall also be
performed after the replacement of any equipment\component forming part
of the overcurrent protection scheme.
These tests may also be used in conjunction with other specialised tests for
corrective maintenance tasks or protection investigations after a system
disturbance.
12.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all feeder/bay overcurrent
relays and schemes.
12.1.3 Reference Documents
Automated test file for the particular application
Relevant commissioning spreadsheet
IEC 60255
12.2 Procedure
12.2.1 Feeder/Bay Overcurrent 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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
48 of 91
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.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
serviceability of any component in the relay, the component shall be
replaced.
12.2.2 Site Data
Record all relevant relay data as per relevant test result forms.
Confirm that the relay is suitable for the application.
12.2.3 Visual Inspection
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.
12.2.4 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(if applicable) secondary circuits
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
49 of 91
DC circuits
o Supply circuits
o Logic circuits
o Tripping circuits
o Alarm circuits
12.2.5 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;
All enable parameter sets shall be tested.
Relay Pick up for all fault loops
Timing
All overcurrent operating characteristics
Directionality of the overcurrent characteristic if applicable
Integrated/External Circuit Breaker Failure Protection functions
Internal/External blocking functions
Relay alarms
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.
12.2.6 Relay Functional Tests
In schemes where more than one relay per bay is installed, all signals
exchanged between these relays – if applicable, 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
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
50 of 91
Power System Simulator test kits shall be used for all the above tests.
12.2.7 Final Tests
On completion of the differential 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 sheet has been completed, all tests assessed and signed off.
12.2.8 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 values displayed by the relay.
This test must be carried out in accordance with the relay manufacturer’s
recommendations. The results of the on load test result shall be recorded in
the appropriate commissioning report.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
51 of 91
13 Transformer Differential Protection Commissioning Procedure
13.1 General
13.1.1 Scope
This document describes the commissioning procedure to be performed on
all transformer differential protection relays on the transmission system.
The tests described in this document should be performed prior to
energisation and when applicable, during subsequent preventive
maintenance. The appropriate tests from this document shall also be
performed after the replacement of any equipment\component forming part
of the feeder differential protection scheme.
These tests may also be used in conjunction with other specialised tests for
corrective maintenance tasks or protection investigations after a system
disturbance.
13.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all transformer differential
relays and schemes.
13.1.3 Reference Documents
Transformer manufacturer manual
Automated test file for the particular application
Relevant spreadsheet
IEC 60255
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
52 of 91
13.2 Commissioning Tests
13.2.1 Transformer Differential 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 test routines, test results and site data shall be recorded on the relevant
test results database.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
serviceability of any component in the relay, the component shall be
replaced.
13.2.2 Site Data
Record all relevant relay data as per relevant test result forms.
Confirm that the relay is suitable for the application.
13.2.3 Visual Inspection
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
53 of 91
13.2.4 External Wiring Tests
All external wiring associated with the protection equipment will be proven in
accordance with standard procedures.
These circuits include;
CT secondary circuits
DC circuits
o Supply circuits
o Logic circuits
o Tripping circuits
o Alarm circuits
13.2.5 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 and parameter
sets 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
Differential Slope\Characteristic
Integrated/External Circuit Breaker Failure Protection functions
Non Differential protection functions as set
Internal/External blocking functions
Relay alarms
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.
13.2.6 Relay Functional Tests
As applicable, confirm the following relay functions as per appropriate
substation design schematic diagrams.
Protection relay circuit breaker tripping
Circuit Breaker Failure Starts
All binary inputs operated correctly for all enabled functions from
source to relay
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
54 of 91
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.
13.2.7 Final Tests
On completion of the differential 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.
13.2.8 On Load Tests
Immediately after load is applied to the transformer, an on load test must be
carried out on the relay to verify the correct summation of all CT’s
contributing to the transformer differential scheme using system load.
This test must be carried out in accordance with the relay manufacturer’s
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
55 of 91
14 Transformer Non Current Protection Commissioning Procedure
14.1 General
14.1.1 Scope
This document describes the commissioning procedure to be performed on
all transformer non-current protection devices/relays on the transmission
system.
The tests described in this document should be performed prior to
energisation and when applicable, during subsequent preventive
maintenance. The appropriate tests from this document shall also be
performed after the replacement of any equipment\component forming part
of the non-current protection scheme.
These tests may also be used in conjunction with other specialised tests for
corrective maintenance tasks or protection investigations after a system
disturbance.
14.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all transformer non-current
based schemes.
14.1.3 Reference Documents
Transformer manufacturer manual
Automated test file for the particular application
Relevant spreadsheet
IEC 60255
14.2 Procedure
Non current based transformer protections refer but not limited to:
Overfluxing protection
Temperature protection
Gas/Bucholz protection
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
56 of 91
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 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 test routines, test results and site data shall be recorded on the relevant
test results database.
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 and parameter
sets shall be fully tested.
All external wiring associated with the protection equipment will be proven in
accordance with standard procedures.
These circuits include;
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
Simulator test kits with the appropriate test plan to prove the following;
Relay Pick up for all fault loops
Timing
Operating Characteristics
Integrated/External Circuit Breaker Failure Protection functions
Internal/External blocking functions
Relay alarms
Relay functional tests shall be carried out to prove:
Circuit Breaker tripping
Circuit Breaker Failure starts
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
57 of 91
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.
On completion of the differential relay tests the following must be confirmed;
Correct Settings applied to relay
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
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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
58 of 91
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.
As applicable, confirm the following relay functions as per appropriate
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.
Test sheet has been completed; all tests assessed and signed off.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
59 of 91
15 Synchronising Commissioning Procedure
15.1 General
15.1.1 Scope
This document describes the commissioning procedure to be performed on
all synchronising schemes on the transmission system.
The tests described in this document should be performed prior to
energisation and when applicable, during subsequent preventive
maintenance. The appropriate tests from this document shall also be
performed after the replacement of any equipment\component forming part
of the synchronising or voltage selection scheme.
These tests may also be used in conjunction with other specialised tests for
corrective maintenance tasks or protection investigations after a system
disturbance.
15.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all synchronising and
voltage selection schemes.
15.1.3 Reference Documents
Bay controller manufacturer manual if applicable
Voltage selection scheme logic diagram and schematics
Automated test file for the particular application
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
60 of 91
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
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
serviceability of any component of the scheme, the component shall be
replaced.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
61 of 91
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.
15.2.4 Visual Inspection
The bay controller and synchronising device 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.
15.2.5 External Wiring Tests
All external wiring associated with the protection equipment will be proven in
accordance with standard procedures.
These circuits include;
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;
Correct Settings applied to relay
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)
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
62 of 91
As commissioned set file was uploaded from the protection relay
Test report has been completed; all tests assessed and signed off.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
63 of 91
16 Station bus zone / circuit breaker failure protection commissioning procedure
16.1 General
16.1.1 Scope
This document describes the commissioning procedure to be performed on
all bus zone / circuit breaker protection schemes on the transmission
system.
The tests described in this document should be performed prior to
energisation and when applicable, during subsequent preventive
maintenance. The appropriate tests from this document shall also be
performed after the replacement of any equipment\component forming part
of the feeder differential protection scheme.
These tests may also be used in conjunction with other specialised tests for
corrective maintenance tasks or protection investigations after a system
disturbance.
16.1.2 Object
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of all bus zone / circuit
breaker failure protection schemes.
16.1.3 Reference Documents
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
64 of 91
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
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 for bus zone and CBF functions
Timing test for bus zone and CBF functions
Differential Slope\Characteristic
Circuit Breaker Failure Protection functions
Non current starts for circuit breaker failure protection
Internal/External blocking functions
Relay alarms
The above tests shall be run for every bay being part of the bus zone circuit
breaker protection scheme.
The protection tests are to be carried out with the ‘in-service’
configuration\settings\marshalling applied.
All test routines, test results and site data shall be recorded on the relevant
test results database.
All non compliances shall be investigated and rectified as necessary. If a
non compliance cannot be rectified, or any doubt exists over the
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
65 of 91
serviceability of any component in the relay, the component shall be
replaced.
16.2.3 Site Data
Record all relevant relay data as per relevant test result forms.
Confirm that the relay is suitable for the application.
16.2.4 Visual Inspection
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.
16.2.5 Overall scheme Functional Tests
As applicable, confirm the following relay functions as per appropriate
substation design schematic diagrams.
CBF function tripping selectivity for all busbar arrangements
Bus Zone tripping selectivity for all busbar arrangements
Scheme blind spots
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.
16.2.6 Final Tests
On completion of the differential 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
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
66 of 91
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.
16.2.7 On Load Tests
Immediately after load is applied to the busbar, an on load test must be
carried out on the relay to verify the correct summation of all CT’s
contributing to the busbar differential scheme using system load.
This test must be carried out in accordance with the relay manufacturer’s
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
67 of 91
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
The object of this document is to provide a minimum set of test procedures
that ensure the integrity and correct operation of the Station Control System.
17.1.3 Reference Documents
Relevant commissioning spreadsheet
Automated test file for the particular application
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
Record all relevant relay data as per relevant test result forms.
Confirm that the bay controller is suitable for the application.
17.2.3 Visual Inspection
The SCS equipment shall be examined to confirm the following:
No physical damage.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
68 of 91
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.
17.2.4 External Wiring Tests
All external wiring associated with the bay controller 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 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.
Secondary current injection tests will be carried out using Power System
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
All LED’s operated correctly for all enabled functions
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
69 of 91
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
All LED’s have been labelled in accordance with the assigned
function(s)
Test report has been completed, all tests assessed and signed off.
17.4 On Load Tests
Immediately after load is applied to the feeder, an on load test must be
carried out to verify the correct power indication on the feeder. Measured
values will be compared between local indication and control center(s)
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
70 of 91
HV Lines
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
71 of 91
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
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 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.
18.1.3 Reference Documents
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
72 of 91
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
73 of 91
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
The objective of this document is to provide a minimum set of test
procedures that verify a newly constructed lattice steel tower is built as per
design specified within the project safety file.
18.2.3 Reference Documents
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
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, tower
orientation and height;
Line Route Map detailing structure locations;
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
74 of 91
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
75 of 91
18.3 Steel Monopole
18.3.1 Scope
This document describes the test procedures to be performed on all new
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
The objective of this document is to provide a minimum set of test
procedures that verify a newly constructed steel monopoles is built as per
design specified within the project safety file.
18.3.3 Reference Documents
Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.
18.3.4 Procedure
18.3.4.1 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,
monopole orientation and height;
Line Route Map detailing structure locations;
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.
18.3.4.2 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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
76 of 91
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.
18.3.4.5 Visual Inspection
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 all steelwork galvanising to verify that it meets design
standard specified in the project safety file;
Inspect the monopole shear block/base to verify that it is installed as
per design;
Verify that the correct Name Plate and Danger Notices are installed
as per design.
110 kV Braced Angle Woodpole
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
77 of 91
18.4 110 kV Braced Angle Woodpole
18.4.1 Scope
This document describes the test procedures to be performed on all new
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
The objective of this document is to provide a minimum set of test
procedures that verify a newly constructed 110 kV braced angle woodpole is
built as per design specified within the project safety file.
18.4.3 Reference Documents
Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.
18.4.4 Procedure
18.4.4.1 Safety File Data
The minimum information a commissioner requires is:
Line Design Sheet detailing structure numbering, type/grade, braced
woodpole orientation and height;
Line Route Map detailing structure locations;
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.
18.4.4.2 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.
18.4.4.3 Visual Inspection
When the braced woodpole 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;
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
78 of 91
Inspect all woodpoles to verify that they meet the design standard
specified within the project safety file;
Verify that the correct Name Plate and Danger Notices are installed
as per design.
110 kV Intermediate Woodpole
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
79 of 91
18.5 110 kV Intermediate Woodpole
18.5.1 Scope
This document describes the test procedures to be performed on all new
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
The objective of this document is to provide a minimum set of test
procedures that verify a newly constructed 110 kV intermediate woodpole is
built as per design specified within the project safety file.
18.5.3 Reference Documents
Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.
18.5.4 Procedure
18.5.4.1 Safety File Data
The minimum information a commissioner requires is:
Line Design Sheet detailing structure numbering, type/grade and
height;
Line Route Map detailing structure locations;
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.
18.5.4.2 Visual Inspection
When the woodpole is fully erected the commissioner must:
Inspect all woodpoles to verify that they meet the design standard
specified within the project safety file;
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;
Verify that the correct Name Plate and Danger Notices are installed
as per design.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
80 of 91
18.6 Conductor & Hardware
18.6.1 Scope
This document describes the test procedures to be performed on all new
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
The objective of this document is to provide a minimum set of test
procedures that verify that new overhead line conductor is strung as per
design specified within the project safety file.
18.6.3 Reference Documents
Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.
18.6.4 Procedure
18.6.4.1 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 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).
18.6.4.2 Visual Inspection
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;
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
81 of 91
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
This document describes the test procedures to be performed on all new
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
The objective of this document is to provide a minimum set of test
procedures that verify newly erected insulators and insulator hardware are
installed as per design specified within the project safety file.
18.7.3 Reference Documents
Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.
18.7.4 Procedure
18.7.4.1 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 insulator arrangement at each structure;
Line Route Map detailing structure locations;
Insulator assembly drawing(s).
18.7.4.2 Visual Inspection
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
82 of 91
18.8 Jumpers
18.8.1 Scope
This document describes the test procedures to be performed on all new
overhead line jumper arrangements before they form part of an energised
circuit. 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.
18.8.2 Objective
The objective of this document is to provide a minimum set of test
procedures that verify that a newly constructed jumper arrangement is
installed as per design specified within the project safety file.
18.8.3 Reference Documents
Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.
18.8.4 Procedure
18.8.4.1 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 locations;
Line Route Map detailing structure locations;
Jumper assembly drawing(s).
18.8.4.2 Visual Inspection
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;
Inspect the overall jumper assembly to verify that it meets the design
specified within the project safety file;
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
83 of 91
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
This document describes the test procedures to be performed on all new
station lead-in connections before they form part of an energised circuit. 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.
18.9.2 Objective
The objective of this document is to provide a minimum set of test
procedures that verify that a newly constructed lead-in connection is
installed as per design specified within the project safety file.
18.9.3 Reference Documents
Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.
18.9.4 Procedure
18.9.4.1 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:
Station lead-in arrangement drawing;
Station lead-in conductor type.
18.9.4.2 Visual Inspection
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;
Inspect the overall lead-in arrangement to verify that it meets the
design specified within the project safety file;
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
84 of 91
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
This document describes the test procedures to be performed on all new
station busbars before they are 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 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
The objective of this document is to provide a minimum set of test
procedures that verify a newly constructed station busbar is built as per the
design specified within the project safety file.
18.10.3 Reference Documents
Current revision of EN 50341-1 and Irish NNA EN 50341-3-11.
18.10.4 Procedure
18.10.4.1 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:
Station busbar support drawing(s);
Station busbar phase design/type.
18.10.4.2 Visual Inspection
When each busbar support 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;
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
85 of 91
Verify that shear blocks are installed as per design;
Verify that the correct Name Plate and Danger Notices are installed
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
design specified within the project safety file.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
86 of 91
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.
19.1.3 Reference Documents
110kV: Current Revision of IEC 60840
220kV: Current Revision of IEC 62067
400kV: Current Revision of IEC 62067
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
87 of 91
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
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.
19.2.2 Objective
The objective of this document is to provide a minimum set of test
procedures that verify that the sheath of a newly constructed HV Cable
Circuit meets the design standard specified within the project safety file.
19.2.3 Reference Documents
Current Revision of IEC 60229
Current Revision of IEC 60840
Current Revision of IEC 62067
19.2.4 Procedure
19.2.4.1 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.
19.2.4.2 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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
88 of 91
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.
19.3.3 Reference Documents
Current Revision of IEC 62067.
19.3.4 Procedure
19.3.4.1 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.
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
89 of 91
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
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.
19.4.2 Objective
The objective of this document is to provide a minimum set of test standards
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.
19.4.3 Reference Documents
Engineering Recommendation C84
HV Cable Manufacturer’s Operation & Maintenance Manuals
19.4.4 Procedure
19.4.4.1 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.
Cable Profile, showing all joint bay locations, all termination locations
and all oil tank locations.
Bonding Diagram, showing phasing of circuit, termination types,
cable type, bonding design, sheath interruptions.
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.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
90 of 91
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
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.
19.5.2 Objective
The objective of this document is to provide a minimum set of test standards
that verify a newly constructed Oil-Filled HV Cable Circuit has adequate oil
insulation along the entire cable route.
19.5.3 Reference Documents
Engineering Recommendation C84
Cable Manufacturer’s Operation & Maintenance Manuals
19.5.4 Procedure
19.5.4.1 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.
Cable Profile, showing all joint bay locations, all termination locations
and all oil tank locations.
Bonding Diagram, showing phasing of circuit, termination types,
cable type, bonding design, sheath interruptions.
Cable Manufacturing Specification, including volume of oil per
kilometre.
Accessories (termination, joints, tanks) Manufacturers Specification,
including volume of oil per accessory.
ESBI Asset Management Services – Commissioning Procedures
DP-040-006
91 of 91
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.