Version 4.0
SAT
(Site Acceptance Test)
1.0
2.0
Table of Content
Site Acceptance Test ................................................................................................................... 2
1.1
Introduction....................................................................................................................... 2
1.2
Purpose ............................................................................................................................ 2
1.3
Scope ............................................................................................................................... 2
1.4
Definitions......................................................................................................................... 3
1.5
Definitions for Special Conditions & Tests ....................................................................... 4
1.6
SAT Process Flowchart.................................................................................................... 4
Appendices ................................................................................................................................... 5
2.1
Requirement/Appendices ................................................................................................. 5
Appendix A : SAT Test Form Requirements
Appendix B : SAT Test Procedure Requirements
Appendix C : SAT Tester and Equipment Requirements
Appendix D : SAT Testing Program Requirements
Appendix E : SAT Defect Logbook Requirements
Appendix F : SAT Drawings, Manuals, Contract Specifications and Relay Settings
Requirements
Appendix G : SAT for Multicore Cable Termination
Appendix H : SAT for Substation AC/DC System
Appendix I : SAT Secondary Injection for Relays and Instruments
Appendix J : SAT for Primary Equipments
Appendix K : SAT for Lines and Cable
Appendix L : SAT Primary Injection Tests for CT Circuit
Appendix M : SAT Secondary Injection Test for Voltage Circuit
Appendix N : SAT for Protection and Control Scheme
Appendix O : SAT Stability Test of Unit/Differential Protection
Appendix P : SAT Final Inspection and Check
Appendix Q : SAT for Secondary Live Maintenance
Appendix R : On load Tests
Appendix S : Post Commissioning Test
Appendix T : SAT Process Flowchart
1.1
Site Acceptance Test
1.1
Introduction
SAT for any new Grid Facilities shall carried out after SCA has passed. The SAT
is carried out by tester, vendor, or TNB. In order to ensure that all SAT is carried
out as per the requirement of TNB Grid, this document has been written. It shall
be used a guideline by all parties involved in the SAT for any Grid Facilities.
1.2
Purpose
The purpose of this document is to:
•
To clearly define the requirement imposed on the tester in ensuring
quality of work and all TNB requirements being implemented accordingly
in TNB Grid facility.
•
To define and standardise the process and requirements of Site
Acceptance Test for TNB Grid Facilities.
•
Provide a reference for the Project Manager, Tester and the Main
Contractor involved in the testing works.
•
Avoid any conflicts that arise at site with regard to tests that are to be
carried out.
This document shall be applicable for SAT carried out to commission all turnkey
and in-house projects of TNB Grid facilities. This shall include but will not be
limited to:
1.3
Scope
•
•
•
•
•
Any Grid / power plant interconnection facility
Both AIS and GIS type substations
Cables And Lines
Digital Substation
Substations installed with Remote Terminal Units (RTU)
Teleprotection end-to-end test shall be covered for the above including
Interconnection to large power consumers, LPC.
For telecommunication equipment only the end-to end is covered in this
document. Refer to ICT procedures.
Energy meters and related equipment are not covered by this document.
Whereas for telecontrol equipment, tests shall be covered up to the regional or
national control center (NLDC) (refer to Appendix Q; 5.0 for the scope of the
work).
Any equipment failure detected during SAT shall be recorded and reported to
TNB to initiate equipment root cause analysis process. A notification (Product
Issue Notification / Product Submission for Investigation) as per Appendix A
shall be filled by Contractor / Tester.
!"
Under TNB Relay Failure Management process, any defect or failure detected
during DV, FAT, SAT and EOW shall be replaced immediately to avoid
impacting project timeline. Any cost incurred related to the replacement work
including testing shall be borne by Main Contractor under project
implementation until EOW period.
1.4
Relay
Failure
Management
The affected relay shall be subject to further failure root cause analysis by OEM
as per the requirement under Product Acceptance Process.
A notification (Product Issue Notification / Product Submission for Investigation)
as per Appendix A shall be filled up immediately after failure is detected by Main
Contractor / Panel Builder and to be submitted to TNB for proper tracking.
1.5
Definitions /
Abbreviations
Terms
TNB
Grid
GAM
PM
End User
Grid Facility
Tester
Energy Commission,
Malaysia (EC)
Electrical Service
Engineer (ESE)
EC Competent
Engineer (ECP)
ESE’s Authorised
Personnel (EAP)
Site Acceptance Test
(SAT)
Pre-commissioning
Inspection and Testing
(PIAT)
Project Quality
Assessment (PQA)
Design Verification
(DV)
Factory Acceptance
Test (FAT)
End of Warranty Test
(EOW)
Definition
Tenaga Nasional Berhad
Grid Division, TNB
Grid Asset Management Department
Project Manager
Grid Asset Maintenance, Distribution Network, ICT
etc.
The Grid substation, line and/or cable eq
uipment (of 66kV and above) or part thereof. However
distribution equipment in the Grid substation shall also
be included.
A testing contractor / Electrical Service Contractor
employing a full-time Electrical Service Engineer.
Suruhanjaya Tenaga Malaysia / Energy Commission
(formerly known as Jabatan Bekalan Elektrik dan
Gas).
Electrical Service Engineer certified by Energy
Commission, Malaysia.
Electrical Competent Engineer certified by Energy
Commission, Malaysia.
A person authorised in writing by the ESE to act on his
behalf for any SAT activity and who fulfils TNB’s
requirements.
Inspection and testing performed at site on the Grid
Facility.
Quality Assessment activity performed by project
manager after the successful completion of SAT stage
2 to determine the readiness of the Grid Facility to
start SAT stage 3 and 4.
Quality Assessment activity performed by AMD after
the successful completion of SAT to determine the
readiness of the Grid Facility to be energised.
Inspection and testing performed prior to FAT, usually
conducted in the presence of TNB representative
Inspection and testing performed after DV and before
the product sent out to site for SAT, usually conducted
by TNB Quality Assurance Inspector (QAI)
Inspection and testing performed prior to warranty
expiry for all Grid Facility
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1.6
Definitions for
Special
Conditions &
Tests
Terms
Live Plant
Live Bay
Unit Protection
Primary Injection
Stability Test
End-to-end test
On load tests
1.7 SAT
Process
Flowchart
Definition
A fenced area with energised high voltage equipment.
Any bay e.g. transformer, line/cable, bus-coupler or
bus-section bay that is being energised at high/low
voltage & DC System. Live means not isolated or not
earthed.
Protection system with a clearly defined zone of
protection usually demarcated between 2 or more sets
of CT’s.
Testing by means of injecting current into the primary
circuit to verify CT ratio, CT polarity and CT secondary
circuits. Primary injection is not considered as stability
test.
Test performed to assess unit protection as a
complete scheme that remains stable for all out-zone
faults and operates only for in-zone faults.
Teleprotection function tests for lines and cables
including carrier send & receive tests, intertripping and
stability test.
Any tests/measurement using the energised
secondary voltage and secondary load current after a
circuit has been energised.
The SAT process is categorized into the following four stages:
•
Stage 1 – Multicore termination checks and AC/DC system
commissioning
•
Stage 2 – Component level testing for primary and secondary
equipments
•
Stage 3 – CT/VT circuit check, switchgear operation test and Control
scheme test
•
Stage 4 – Protection scheme test, stability test and trip test
•
Stage 5 – On Load test and Post commissioning test
These stages shall be carried out as the above-mentioned sequence. For
completeness of the commissioning process PIAT and PQA will be conducted.
Appendix T provides explanation and illustration of the SAT process flow in
further detail.
!"
2.0
Appendices
The primary objective of this document is to provide guidance on ‘what tests shall
be carried out’ instead of ‘how the tests are to be carried out’.
2.1
Requirement/
Appendices
In addition to the question of ‘what tests’, certain specific requirements required to
carry out a particular test is also mentioned.
The following documents shall provide specific requirements of the SAT:
No.
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
Document
SAT Test Form Requirements
SAT Test Procedure Requirements
SAT Tester and Equipment
Requirements
SAT Testing Program Requirements
SAT Defect Logbook Requirements
SAT Drawings, Manuals, Contract
Specifications and Relay Settings
Requirements
SAT for Multicore Cable Termination
SAT for Substation AC/DC System
SAT Secondary Injection for Relays and
Instruments
SAT for Primary Equipments
SAT for Lines and Cables
SAT Primary Injection Tests for CT
Circuit
SAT Secondary Injection Test for
Voltage Circuit
SAT for Protection and Control Scheme
SAT Stability Test of Unit/Differential
Protection
SAT Final Inspection and Check
SAT for Secondary Live Maintenance
On load Tests
Post Commissioning Test
SAT Process Flowchart
Appendix
Appendix A
Appendix B
Appendix C
Appendix D
Appendix E
Appendix F
Appendix G
Appendix H
Appendix I
Appendix J
Appendix K
Appendix L
Appendix M
Appendix N
Appendix O
Appendix P
Appendix Q
Appendix R
Appendix S
Appendix T
.
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SAT Appendix A: SAT Test Form Requirement
1.0
2.0
3.0
Purpose ...................................................................................................................................... 1
General Requirement ................................................................................................................. 1
Additional Requirement .............................................................................................................. 2
1.0
Purpose
The purpose of specifying the test form requirement is to standardise the:
•
•
•
•
2.0
General
Requirement
Content of the test form
Method of recording the test results
Procedure for verifying the test result
Procedure for validating the test form
The following general information shall be mentioned and standardize in any test
form used by the tester.
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
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Name Of The Testing Company
Contract No.
Tender No.
Title of the test form
Name of the substation or installation being tested
Name Of Client – name of main contractor
Bay or Circuit identification – Feeder name
Bay identification – by number/code (bay number)
Manufacturers details e.g. Make, Model, and Type etc.
Test equipment details – name, serial number, calibration record etc
Settings Reference including version.
Testers Name – Name of person conducting the test
Witnessed By – Name of the appointed TNB staff
Verified By – Name and seal of the ESE
Comment - ESE shall comment whether the particular test has passed or
failed.
Page number or Sheet no.
Test Procedure Reference No. – With reference to the particular test
procedure described in Appendix B.
Date.
# #
3.0
Additional
Requirement
In addition to the above general requirements, the following shall also be adhered
to:
a.
All tests conducted shall be documented on a proper test form.
b.
Expected values shall be presented on the test form for all test/measurement
results. A test shall only commence when the expected range of values of
the test is available and presented on the test form. Where the test result
involves obtaining a particular measurement, then error calculation for each
measurement shall be made available on the test form.
c.
For testing where the value of the injection can be obtained – this value shall
be recorded. For testing performed to check a function, the result should be
recorded as “OK” if the test/check results is as expected, “FAIL” if the
test/check result is not as expected, “NR” if the test/check is not required.
Ticking “/” as result shall not be practised. No test result column shall be left
blank.
d.
For test/check result that is not within the expected range, the tester is
required to mention it clearly in the comment column of the test form. The
tester is also required to immediately update this defect in the Master Defect
List (MDL) log.
e.
All results shall be entered onto the test form immediately upon completion
of a test. Recording test results elsewhere and later transferring it onto the
test form shall not be practised.
f.
The witnessing personnel shall initial each test result table in a test form
separately immediately after each test. It is the tester’s responsibility to get
all the test results initialled immediately by the witnessing personnel. Any
test result not initialled by the witnessing personnel will not be accepted.
g.
All test results recorded on the test form shall be crosschecked with the
manufacturer’s factory data whenever available.
h.
Results shall be recorded using black/blue ink and any changes shall be
crossed and initialled in red ink.
i.
A reference to the test equipment manuals and test procedure used shall be
clearly mentioned on the test form.
j.
Print out from test equipment shall be attached with the test report whenever
available.
k.
All test result valid for six months if the station was idle condition. Re-testing
shall be conducted. Tester shall prepare a risk assessment report and
propose on test to be re-conducted. TNB to review and approve the retesting to be done
l.
Any equipment failure detected during SAT shall be recorded in (Product
Issue Notification / Product Submission for Investigation) form as attached
and report to TNB to initiate equipment root cause analysis process.
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Protection, A utomation & Control
GRID SOLUTION EXPERTISE
RELAY FAILURE MANAGEMENT
Product Issue Notification / Product Submission for Investigation
REQUESTOR
Reference No:
TNB/GRID/GSE(PAC)/RFM 3/1/100
Purpose:
Product Issue Notification ……………………………….
Submission for RCA
Product Information:
Installation Information:
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Problem Statement:
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Submission Checklist:
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Issue/Failure During FAT and SAT:
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Submission by:
Name
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Contact No
Submission Date:
10/07/2017
RFM No.:
Received Date:
Delivery Date to OEM:
Updated by:
Update System Date:
OEM Contact Person:
For Secretariat Use:
SAT Appendix B: SAT Test Procedure Requirement
1.0
2.0
Purpose ..................................................................................................................................... 1
General Requirements .............................................................................................................. 1
1.0
Purpose
The purpose in preparing the testing procedure is to:
•
•
•
2.0
General
Requirements
Study & comment on the given procedure before carrying out the test
Document the testing method used for future reference
Be used as a site reference for the tester/witnessing personnel
a.
Testers are required to prepare test procedures for all tests and scheme
check, explaining in detail the steps taken to conduct each test. These test
procedures shall conform to certain standards and practises.
b.
The following information shall be clearly mentioned in each test procedure.
i. Step by step instructions on how the test is performed.
ii. Connectivity diagram of the test setup.
iii. Detail of the test equipment used by the tester. The test equipment used
shall comply to Appendix C
iv. Reference made to an international standard e.g. IEC, BS or equipment
manuals.
v. Any calculation required prior to conducting the test.
vi. Test result form of the particular test. Preparation of the test result form
shall comply to Appendix A
vii. All safety aspects of performing a particular test shall be documented
such as getting appropriate PTW, placing danger signs etc.
viii. A checklist on the preparation required before carrying out the test.
ix. A checklist on the normalization required after performing the test.
c.
Additional specific requirements, instructions or precautionary notes shall be
clearly mentioned in the test procedure if it is to be used in a live substation.
d.
A copy of the complete test procedure shall be handed over to the PM in
advance for comments before commencing with the SAT.
e.
Tester shall be able to provide explanation on the testing procedure upon
request by the witnessing personnel.
f.
All safety aspects required to carry out the test shall be clearly documented in
the test procedure.
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SAT Appendix C: SAT Tester and Equipment Requirement
1.0
2.0
3.0
4.0
Purpose ..................................................................................................................................... 1
Testers Role & Responsibility ................................................................................................... 1
Test Equipment Requirements ................................................................................................. 2
Requirements To Be A Tester .................................................................................................. 2
1.0
Purpose
The purpose of specifying tester and test equipment requirements are:
•
•
•
•
To ensure that the tester abides to all TNB and Energy Commission
regulations.
To ensure the safety of the personnel and equipments.
To ensure that the ‘right’ test equipment is used for the ‘right’ test.
To ensure that the equipment used meets certain specified international
standard and is properly calibrated.
a. All protection & control related test results shall only be endorsed by an
Electrical Service Engineer (ESE).
2.0
Testers
Role &
Responsibility
b. Tester to ensure scheme is in compliance to the approved conceptual
drawing.
c.
c.
For any SAT activity in a live plant e.g. extension work:
i.
The Permit to Work shall be taken by an Energy Commission certified
Electrical Service Engineer or his authorised Energy Commission
Competent Engineer who fulfils TNB’s requirements.
ii.
All activity shall be documented in detail and the Service Engineer shall
endorse this.
For any SAT activity performed on a live station involving any live bay (with or
without outage) e.g. scheme modification, relay changing and testing. Risk
analysis report shall be produced prior to obtaining PTW. Risk analysis shall
consist of the following: i.
Activity to be carried out detailing the risks to the system, the rest of the
plant, or to personnel involved.
ii.
Steps taken to minimize any risks identified to the system, the rest of the
plant, or to personnel involved.
iii. Step by step instruction on all activities to be carried out.
iv. Checklist before carrying out the activities e.g. all isolations to be made.
v.
Checklist after carrying out the activities to re-energize the bay.
vi. The risk analysis report shall be endorsed by Electrical Service Engineer
(ESE).
d. Any protection and control related activities on a live or commissioned bay
shall require the presence and direct supervision of the Electrical Service
Engineer or his authorized personnel.
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a. General requirement for test equipments are:
3.0
Test
Equipment
Requirements
i.
All test equipment used shall be calibrated by a recognized body e.g.
SIRIM and proof of this shall be made available upon request at site.
ii.
Test equipment used shall be calibrated at least once in every two years.
iii. Tester shall produce upon request the manual of the test equipment used
for the reference of the witnessing personnel at site.
iv. Tester shall be able to provide explanation on ‘how to operate’ the test
equipment upon request by the witnessing personnel.
v.
PC based test equipment are preferred. Secondary injection set shall be
able to produce pure sinusoidal waveform for voltage and/or current.
vi. For scheme/relays with 3-phase voltage and 3-phase current input, tests
for such a case shall use appropriate 3-phase voltage and 3-phase
current injection test equipment.
vii. The test procedure as per Appendix B, shall clearly explain how the test
equipments used is wired and configured to carry out a particular test.
b.
Test equipment used shall have built-in safety features in order to avoid any
damage to the relay/instrument being tested and to personnel from accidental
high voltages/currents injection.
c.
Safety procedure of using specific test equipment as documented in the test
procedure (Appendix B) for a particular test shall be followed especially when
carrying out high voltage test.
a) Any tester, in order to be considered eligible to be engaged to undertake any
pre-commissioning, commissioning or any other related work in transmission
facility, shall comply with the following requirements:-
4.0
Requirement To
Be A Tester
•
•
Be a registered company with the EC as an Electrical Service Contractor
and have in his employment a full time ESE. The ESE shall register
himself with the EC as an Electrical Service Engineer.
Registered with TNB Transmission Division, as a qualified tester.
b) The tester shall have in his possession the adequate testing equipments and
instruments to perform the relevant tests. The ESE and authorized person
shall be able to operate all the testing equipments correctly and safely.
c) The tester shall follow the procedures as outlined in the TNB Transmission
facility Site Acceptance Test.
d) The tester shall submit work program, work procedures, checklists and risk
analysis report (if required) for approval before work can be commenced.
e) The ESE is accountable for all of the testing & commissioning works.
However the ESE may also delegate certain works to his ECP or EAP for
them to carry out. Thus, in order to ensure that all the pre-commissioning
activity is carried out as per the TNB Transmission Safety and SAT
requirements, the respective person shall be present during the activity as
tabulated in table 1:
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Table 1
Note
1. To take Permit to Work (PTW) – for SAT activity in a live plant.
ECP shall be allowed to take PTW for Site Acceptance Test (SAT) provided that;
a) The ECP is employed and registered by the Tester / Electrical Service
Contractor (ESC).
b) The ECP holds a valid EAP certificate under that ESC.
c) Submitted the Risk Analysis Report (refer to Appendix C. para 2.c)
2. To take PTW for construction in a live plant.
ECP‘s other than Note 1 above are only allowed to take PTW for construction
purposes.
f)
The tester shall submit list of name of his team members before work can be
commenced.
g) Changes or replacement of ECP or EAP shall not be allowed in an ongoing
project without the consent from the TNB.
h) The tester shall be suspended or deregistered from TNBT Panel of Testers
for the following reasons: •
•
i)
Violation of condition as imposed in clause (a) to (g) of this paragraph.
Cause a tripping or mal-operation, which has been proven to be due to
his negligence.
TNB may review / withdraw the suspension upon complete and satisfactory
fulfilment of any other condition imposed thereby.
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SAT Appendix D: SAT Testing Schedule Program Requirements
1.0
2.0
3.0
Purpose ..................................................................................................................................... 1
General Requirement ................................................................................................................ 1
Additional Requirement ............................................................................................................. 1
1.0
Purpose
The purpose of this section is to provide a guideline when preparing the testing
program in order to:
•
•
•
2.0
General
Requirement
Standardise the content of the test program.
Avoid too many activities being carried out simultaneously.
Plan the sequence of the tests.
a.
The testing schedule prepared by the tester/ main contractor shall be
submitted and accepted in advance by TNB Transmission prior to the
commencement of the SAT.
b.
The testing program shall be prepared in such a way that:
Not too many testing activities are carried out simultaneously (preferably
not more than two at the same time).
Means of recording the actual progress at site shall be provided on the
test form.
The main contractor shall coordinate the activities of all the testers
involved (if different testing companies are involved).
If there are any changes in the testing program during the SAT:
1. These changes shall be informed in written by the tester to the PM.
2. One week advance notice on the changes shall be given before the
test.
3. Upon receiving information on the changes, the PM shall inform
Asset Maintenance.
Testing activities during public holidays, weekends or after office hours
shall only be carried out if agreed upon by the PM.
A daily updated test program on the test progress shall be kept at site.
(To be displayed at site)
Daily briefing on next day activities
3.0
Additional
Requirement
Upon completion of the SAT, the final updated testing program shall be compiled
and documented together with the test reports.
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SAT Appendix E: SAT Defect Logbook
1.0
2.0
Purpose ..................................................................................................................................... 1
General Requirement ................................................................................................................ 1
1.0
Purpose
The purpose of having a defect logbook during SAT is to:
•
•
•
•
•
2.0
General
Requirement
Standardize defect logging method
To monitor the progress of the rectification work
To ensure all critical outstanding work has been completed
To confirm whether the plant is safe to be energized
To assist the PM in producing the final Master Defect List which is
required during PQA.
a.
The PM is responsible to prepare a defect logbook at site titled “SAT
Defects”, to record all defects found during the SAT.
b.
Upon identifying a defect or irregularity, the immediate action shall be to:
Inform the PM verbally
Record the defect in the SAT defect logbook
c.
The detail of each defect, shall include but will not be limited to the following:
Defect/item no. – A unique reference number for the particular defect.
Location of defect – bay name followed by equipment name
Detail of defect – a brief description of the defect
Date Reported – Date the defect was reported
Reported By – The person who reports the defect.
Rectification target date – The proposed target date for rectification.
Action By – Party responsible to rectify the defect
Action Taken – Activity taken to rectify the defect
Date Rectified – Date when the defect was rectified
Critical/Non critical status – Each defect shall be categorized as critical or
non-critical based on the TNBT definition of critical/non-critical defects.
Status – The status of action on the defect item – “DONE” – if completed,
“OS” – if still outstanding, “IP” if the rectifying action is in progress.
d.
A copy of this logbook shall be made available upon request.
e.
The PM is responsible to update this defect logbook every day.
f.
Any minor defect identified and rectified shall also be mentioned in the defect
logbook.
g.
Any rectification shall only be carried after obtaining appropriate approval
from the relevant parties involved.
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SAT Appendix F: SAT Drawings, Manuals, Contract Specifications, Relay
Settings and Substation Configuration Files Requirements
1.0
2.0
3.0
4.0
Purpose ..................................................................................................................................... 1
Definition ................................................................................................................................... 1
General Requirement for Drawings & Manuals ........................................................................ 1
Relay Settings & Related Documents ....................................................................................... 2
The purpose in establishing the SAT requirements for drawings, manuals,
contract specification, relay settings and substation configuration files are:
1.0
Purpose
•
•
•
•
•
•
•
•
2.0
Definition
3.0
General
Requirement for
Drawings &
Manuals
To ensure all documentation required to commence with the SAT is
adequate, complete and available at site.
To ensure that these documents are updated continuously during the process
of SAT.
To facilitate and expedite the process of preparing the as-built
documentation.
To ensure that SAT for relays is carried out with the approved final settings.
To ensure that work is done in accordance to the contract specification.
To ensure proper handing over of required documents in hardcopy and
softcopy format to TNB cloud for storage.
All the softcopy files shall be named based on standard naming approved by
TNB.
PM is responsible to store these documents in TNB document repository,
such as Enterprise Content Management (ECM) System.
i.
Working Copy : Set of drawings used by tester.
ii.
Master Copy : Set of drawings where all updating is done neatly for any
discrepancies found or design changes based on the
corrections in the working copy.
All drawings, manuals, contract documents, equipment factory test reports,
design verification report and TNBR Factory Acceptance Test report of the
plant to be commissioned shall be complete and made available at site
before the SAT commences.
At least two sets of complete drawings shall be made available at site. One
set of the drawings shall be labeled as “Master Copy” and the other as
“Working copy”
The working copy is intended for the tester for testing purposes, which shall
be used to update any discrepancies found during the SAT.
The master copy shall be maintained and updated by the main-contractor
daily. The updating shall be done neatly using only red ink. The name and
date shall be indicated in revision column of the title block. The master copy
shall be made available at site during SAT.
During the SAT, the PM is responsible to ensure that manuals for all
secondary and primary equipments are complete.
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a. A complete set of the final relay settings approved/endorsed by the
Protection Setting Unit (PRST), Grid Maintenance Department of TNB and
relay configurations shall be made available at site by the PM.
3.0
Relay
Settings &
Related
Documents
b. SAT for relays shall
setting/configuration.
c.
carried
out
with
the
approved
final
The relay setting/configuration document shall include both the settings
issued by PRST Unit and the complete configuration of the relay. The relay
configuration shall include but will not be limited to the following:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
d.
be
Relay Binary Output contacts configuration
Relay Opto Inputs configuration
Relay LED/Relay Indication configuration
Relay Event List configuration
Relay Scheme Logic
Publisher/Subscriber GOOSE configuration
Client/Server MMS configuration
System Configuration Description (SCD) file
For numerical and/or digital relays, the submission for relay setting and
configuration endorsement shall include :
i.
Declaration by ESE confirming that the tested and implemented relay
settings for the devices have been validated to be as per intended design
ii. Setting comparison result between setting in the relay and setting issued
by PRST in PDF format with verification by ESE
iii. Relay setting and configuration file in relay native software format named
with standard naming convention
For non-numerical relays, the submission for relay setting and configuration
endorsement shall include :
i.
ii.
Declaration by ESE confirming that the tested and implemented relay
settings for the devices have been validated to be as per intended design
Relay setting in hardcopy format
e. The System Configuration Description (SCD) file shall be verified to ensure
the correct version with reference to Design Verification version. Any changes
made to the SCD file will need to be approved by TNB GSE and recorded in
the Master Defect List (MDL). The final copy shall be handed over to TNB to
store in ECM.
f.
PM shall ensure all relay setting and configuration, drawing and SCD file (if
required) endorsed and verified by all related parties before PQA.
g.
The PM shall be responsible to ensure all parameters used for setting
calculation are accurate e.g. CT ratio, line length, and all protection scheme.
h.
All the required document as per item c shall be handed over to TNB in a
softcopy format.
#
! "
# #
SAT Appendix G: Multicore Cable & Communication Cable Termination Check
& Test
1.0
2.0
3.0
4.0
5.0
6.0
Purpose ..................................................................................................................................... 1
General Requirement ................................................................................................................ 1
Commencing Multicore and communication cables Termination Check .................................. 1
Performing Multicore and communication cables Termination Check...................................... 2
Performing Multicore and communication cables Termination Test ......................................... 3
Recording Multicore and communication cables Termination Check & Test Result ................ 3
1.0
Purpose
In order to minimize problems during the SAT functional and scheme test, a
thorough check & test for all multicore and communication cables termination
shall be carried out. The purpose of Appendix G is to provide guidelines on:
•
Requirements prior to multicore and communication cable termination
check & test
Checks required to be carried out
Tests required to be carried out
•
•
Communication cables cover fibre optic, CAT5e/6, twisted pair, etc.
2.0
General
Requirement
a.
The prerequisite to the commencement of SAT is to successfully complete
the multi-core & termination check and tests. No SAT activities shall proceed
unless all multicore and communication cables termination has been
confirmed to be in order.
b.
The same tester performing the SAT shall carry out the multicore and
communication cables termination check and test.
c.
All multicore and communication cables of the facility to be commissioned
shall be checked and tested. This shall include multicore cables from
switchgear cubicles/panels to the Marshalling Kiosk, communication cables
between communicating devices and all other cables between
cubicles/panels.
d.
Multicore and communication cables block diagram shall be included with
the multicore and communication cables schedule.
a. Multicore and communication cables termination check and test shall only
commence once:
3.0
Commencing
Multicore and
communication
cables
Termination
Check
!"
i.
A complete and updated cable core schedule has been made available
to the tester and the PM by the main-contractor. Main-contractor shall
perform the responsibility as required by the contract and Tester Terms
of Reference (TOR).
ii.
All multicore and communication cables termination activities have
been properly completed. Cable numbering, terminal block numbering,
core numbering and ferrule numbering shall be in accordance with the
specification and arranged neatly.
# #
a. Requirements of the contract specification shall be used as a reference for
carrying out multicore and communication cables termination check.
4.0
Performing
Multicore and
communication
cables
Termination
Check
b. For multicore cable, at least the following shall be checked and confirmed
to be in accordance with the cable core schedule:
The multicore cables are numbered at both ends.
The multicore cables core size used.
The multicore cables colour.
The multicore screen/armour is effectively grounded if applicable.
All spare cores are numbered if applicable.
Check all spare multicore are separated numbered (cable and ferrule
number) and grouped according to cable number.
The terminal blocks type and numbering.
No jointing along the multicore cables.
Type of cable marker and ferrule used.
Core numbering and terminal block numbering.
The termination is neat, proper and tight.
Correct size of cable glands and lugs are used.
Separate multicore cables used for AC/DC circuit.
c.
For fiber optic cable, at least the following shall be checked and confirmed
to be in accordance with the general guideline as per annexed in this
Appendix:
i.
ii.
iii.
iv.
The communication cables are numbered at both ends.
The communication cables type, wavelength, cores size and mode.
The communication cables screen/armour is effectively grounded if
applicable.
v.
All spare cores are numbered and terminated appropriately.
vi.
The termination at patch panel (if applicable) and connectors of fibre
optic is neat, proper and tight.
vii.
Ensure proper fibre optic laying method is applied to reduce
macrobending and microbending effects, such as :
• No bending, snagging and kinking
• Dedicated fiber optic trunking within panels
• Dedicated fiber optic cable tray at cable cellar
• Excessive fiber optic shall be coiled and managed with Cable
Management
#
!"
# #
5.0
Performing
Multicore and
communication
cables
Termination
Test
a.
At least the following test shall be performed on each multicore cable:-
b.
Insulation resistance at 1kV DC. Any equipment, which may be damaged
by the application of the test voltage, shall have the appropriate terminal
isolated or short-circuited.
c.
Continuity check.
d.
The following tests shall be performed on each fibre optic communication
cable, inclusive of all the patch cords and armored fiber cables. The testing
reference is annexed in this Appendix :a. Fibre or Power Loss measurement to ensure the decrease in power
loss measured in dB is acceptable
b. Cable continuity by verifying the laser transmitted from a source is
visible at the opposite end
Power Measurement equipment requires calibration on the
measurement range used based on the international standards. The
equipment shall have a good resolution with the intention to measure
loses over a short length of fiber cable.
6.0
Recording
Multicore and
communication
cables
Termination
Check & Test
Result
a.
Preferably the cable core schedule itself should be used to record all the
above checks/tests for each core/channel.
b.
Any discrepancies found on the cable schedule shall be updated
immediately.
c.
Upon completion of the multicore and communication cables termination
check and test, the final updated cable core/channel schedule shall be
available at site for the PIAT / PQA inspection and later for the production
of the as-built version.
$
!"
# #
SAT Appendix H: SAT for Substation AC/DC System
1.0
2.0
3.0
Commissioning of AC Board ..................................................................................................... 1
Commissioning of Battery Charger System .............................................................................. 1
Testing of Battery Bank & DC Distribution Board ..................................................................... 2
1.0
Commissioning
of AC Board
Tests required to commission the AC Board:
a.
b.
c.
d.
e.
f.
g.
h.
i.
Test AC configuration is as per the single line diagram provided.
Perform DC insulation resistance test for the AC Board.
Test all indicating meters and lights of the AC Board.
Test all relays where applicable.
Test AC distribution circuits and ensure the labelling is in order.
Test any interlock provided on the AC board.
Test that the AC sources are not paralleled at the distribution side.
Test on transducer if available.
To ensure all outgoing feeders for charger, transformer supplies are
distributed on different section of AC bus bar
2.0
Commissioning
of Battery
Charger System
a.
Preferably, the commissioning of the battery charger shall be performed by
the charger manufacturer.
b.
Implement all charger settings.
c.
The Charger shall be commissioned first before being connected to the
batteries.
d.
Test form as required in Appendix A shall be provided. The following
additional information shall be included in the test form:
Complete charger details
Complete battery details
Complete charger settings
e.
At least the following tests shall be performed. In addition to the tests
required/recommended by the manufacturer, the tests to be performed shall
include but will not be limited to the following: Boost interlocking scheme
Float voltage setting
Boost voltage setting
Boost charging current
High voltage alarm setting
Low voltage alarm setting
A/C fail condition
Charger fail condition
Low electrolyte level alarm
DC earth fault – positive and negative
Transducer (if available)
f.
! "#
All facia for the above test shall be recorded.
$ $
3.0
Testing of
Battery Bank
& DC
Distribution
Board
a.
Test form as required in Appendix A shall be provided.
b.
In addition to the tests recommended by the manufacturer, the tests to be
performed shall include but shall not be limited to the following: Complete charge and discharge test for all battery cells including the
spares. Appropriate equipment with constant current discharge shall be
used.
Discharge test shall be carried out for a minimum duration of 8 hours.
Specific gravity measurement shall be taken at the start and end of the
discharge test.
Voltage measurement for each cell shall be taken hourly during
discharge test.
Terminal connection tightness check. (Torque check – as per
recommended by manufacturer).
Check all battery cell, isolation fuse, distribution board, MCB are labeled
clearly.
Checks that the Distribution Board is configured as per the single line
diagram and confirm labeling of all distribution MCB’s are in order by test.
The insulation to earth of the complete DC installation shall be tested.
Test battery bank isolation system.
Open circuit voltage of the battery when it is fully charged shall be
measured and recorded.
Multicore cable shall be checked as per Appendix G.
$
! "#
$ $
SAT Appendix I: SAT for Secondary Injection of Relays and Instruments
1.0 Purpose ............................................................................................................................................. 1
2.0 General Requirement ........................................................................................................................ 2
3.0 Protection and Control functions ....................................................................................................... 5
3.1 Line Differential Protection Function ................................................................................................. 5
3.2 Pilot Wire Protection Function ........................................................................................................... 5
3.3 Distance Protection Function ............................................................................................................ 6
3.4 Autoreclose and Synchronizing Check Function .............................................................................. 6
3.5 Thermal Overload Function............................................................................................................... 7
3.6Transformer/Reactor Bias Differential Protection Function ............................................................... 7
3.7 Transformer / Reactor High Impedance Protection and Restricted Earth Fault Function ................ 8
3.8 Overcurrent Protection Function ....................................................................................................... 8
3.9 Standby Earth Fault Protection Function .......................................................................................... 9
3.10 Busbar and Stub High Impedance Protection Function .................................................................. 9
3.11 Low Impedance Busbar Protection Function ................................................................................ 10
3.12 Breaker Failure Protection ............................................................................................................ 10
3.13 Manual synchronizing Check Protection Function ........................................................................ 10
3.14 Demand/Load Shedding Function ................................................................................................ 11
3.15 Automated Voltage Regulator Function ........................................................................................ 11
3.16 Unbalanced Capbank Protection Function ................................................................................... 11
3.17 Overload Capbank Protection Function ........................................................................................ 12
3.18 Under Voltage Or Over Voltage Capbank Function...................................................................... 12
3.19 Point of Wave Controller ............................................................................................................... 12
3.20 Earth Switch Under Voltage Function ........................................................................................... 12
3.21 Transducers/ Meters or Instrument Meter (DPM) Function .......................................................... 13
3.22 Input and Output IED .................................................................................................................... 13
4.0 Integrated Protection and Control applications ............................................................................... 13
4.1 Integrated Line Protection ............................................................................................................... 13
4.2 Integrated Backup Distance with Thermal Overload Protection ..................................................... 13
4.3 Circuit Breaker Management .......................................................................................................... 13
4.4 Bay Controller ................................................................................................................................. 13
4.5 Overload and Overcurrent Capbank ............................................................................................... 13
4.6 Overvoltage and Undervoltage Capbank ........................................................................................ 13
5.0 Functional Test Guideline ............................................................................................................... 14
5.1.1 Current Differential Function: Pick Up Test.................................................................................. 14
5.1.2 Current Differential Function: Timing Test .................................................................................. 14
5.2.1 Distance Function: Reach Test .................................................................................................... 14
5.2.2 Distance Function: Reach Test: Timing Test ............................................................................... 15
5.2.3 Distance Function: Reach Test: SOTF & TOR Test .................................................................... 15
5.2.4 Distance Function: VTS Test ....................................................................................................... 15
5.3.1 Autoreclose Function: Pick Up Test ............................................................................................. 16
5.3.2 Synchronizing Function: Pick Up Test ......................................................................................... 16
5.3.3 Synchronizing Function: Voltage Check ...................................................................................... 17
5.4.1 Transformer Biased Differential Function: Timing Test (Lower & Upper Slope).......................... 17
5.4.1 Transformer Biased Differential Function: Biased Characteristic Test ........................................ 18
5.5.1 High Impedance Differential Function: Biased Characteristic Test ............................................. 18
5.5.2 Hi Impedance Function : Pick Up And Timing Test ..................................................................... 18
1.0 Purpose
To provide SAT requirements in carrying out secondary injection tests for all
types of control, protection and instrument devices as an individual component
! "#
$ $
2.0 General
Requirement
a. Secondary injection shall only commence once stage 1 of the flowchart as per
Appendix S has been completed.
b. Secondary injection shall be carried out on all relays and instrument with
voltage and/or current inputs.
c.
The relay shall be tested with its final approved/endorsed setting &
configuration. Verify the relay setting, such as CT or VT ratio as per actual
site.
d. Verify and record that all relays are configured to TNB’s approved standard
configuration, Terminal Functional Diagram (TFD). It shall include BI, BO and
LED. For Digital Substation, this also included Virtual Input, MMS and
GOOSE.
e. Relay settings used to test the performance of the relay shall be noted in the
test form before injection.
f.
Secondary injection shall only be carried out using dedicated test facilities
provided for the protection relay or instrument
g. Check and record all protection relays, instruments, test terminal blocks, trip
links and group isolation links are labelled clearly as per specification and
approved drawing.
h. Check and record that by inserting/removing the test plug, trip link and group
isolation link, the following action will take place:
The DC supply for the relay or instrument is not interrupted.
The signaling circuits for alarm, fascia, and SCADA and digital recorder
are not interrupted.
Tripping circuit inclusive Breaker Fail start, initiation of Master trip to be
isolated
Control circuit inclusive A/R initiation signal, A/R closing command to be
isolated (whichever applicable)
Insertion of test plug shall isolate in the following sequence:• First, all tripping signals from the relay are isolated.
• Followed by the incoming current circuits are short-circuited.
• Finally, the incoming voltage circuits are open-circuited.
i.
In addition to test required in this document, all tests required by the relay or
instrument manufacturer shall also be performed.
j.
For relay and instruments with three phase voltage and/or current inputs, e.g.
distance protection relay, the test equipment used shall be computer based
with at least three-phase voltage and current output.
k.
Any repair work on a relay after the completion of secondary injection tests,
shall subject the relay to a full retest.
l.
Any relay configuration and setting changes on a relay after the completion of
secondary injection tests, shall subject the relay to a full retest.
For protection relays, all functions that are in use (configured and setting) shall be
tested. Any function not in use shall be proven to be defeated.
m. For relays with the group settings function, all the setting groups in use shall
be tested e.g. Directional Overcurrent relay.
$
! "#
$ $
n.
The pickup setting for a particular type of protection shall be established by
secondary injection, where it is impractical to ascertain this value by primary
injection. Injection shall be made across the appropriate relay bus wires with
all associated relays, setting resistors and CTs connected.
o.
Each relay must be provided with a test form. In addition to the general
information required in a test form as in Appendix A, at least the following
details of the relay under test shall be mentioned:
Relay Make
Relay type
Version No.
Relay input rating – Vac, Iac, Hz, Vdc
Burden (VA)
Serial No.
Year of manufacturing
p.
All test plug terminal numbers used during secondary injection shall be
mentioned in the test form.
q.
Expected results and/or acceptance criteria of the test shall be made available
prior to any test. In general, 5% error tolerance is acceptable unless specified
by manufacturer for pick up test. For timing test, additional 30ms is allowed to
accommodate relay operation time and contact made time. For Under/Over
Frequency & Under/Over Voltage relay, the expected relay operation time and
contact made time depends on the design and internal algorithm.
r.
Timing test for any contacts initiating tripping inclusive direct trip and master
trip circuit.
s.
Error shall be recorded for any results obtained.
t.
During secondary injection of protection relays, all output contacts shall be
monitored and recorded for its functionality as per TFD. For example:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
Contacts initiating trip circuits
Contacts initiating master trip relay
Contacts initiating breaker failure
Contacts initiating auto-reclose
Contacts initiating counter/HMI (Digital Substation)
Contacts initiating annunciator
Contacts wired to digital fault recorders
Contacts wired to SCADA
GOOSE signal to associated IED
MMS signal to clients
For example, during overcurrent secondary injection test, the performance of all
output contacts used can be recorded in the following format (Table 1):
Function to
be tested
OC Definite
OC High
Set
OC Start
OC IDMT
EF High
Set
OUTPUT CONTACT OPERATION
Lockout Counter
SCADA
Trip
Trip
Ct. 1
Trip
Ct. 2
Yes
No
Yes
No
Yes
No
Yes
No
No
Yes
No
No
Yes
No
No
Yes
No
No
Yes
No
Dist.
Rec.
Alarm
Yes
No
Yes
No
Yes
No
No
Yes
No
No
Yes
No
No
Yes
No
%
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$ $
EF Start
EF IDMT
DC Fail
No
Yes
No
No
Yes
No
No
Yes
No
No
Yes
No
No
Yes
No
No
Yes
No
No
Yes
Yes
Table 1
For Digital Substation, Table 2 can be referred.
Function
to be
tested
OC
Definite
OC High
Set
OC Start
OC
IDMT
EF High
Set
EF Start
EF
IDMT
DC Fail
Trip
Ct.
1
OUTPUT CONTACT/VIRTUAL OUTPUT OPERATION
Trip Lockout Fascia SCADA Digital
HMI
Ct.
Trip
Rec.
(Alarm)
2
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
No
No
No
No
No
No
No
No
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
No
No
No
No
No
No
No
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
Yes
No
No
No
Yes
No
No
Yes
Yes
EGW
(Alarm)
Table 2
u.
Test and record all digital inputs and GOOSE inputs (Digital Substation) as
per TFD of a protection relay or instrument.
v.
Test and record the functionality of the all possible communication
interrogation facility of the relay e.g. PC-relay communication or remotely if
applicable.
w. Test and record all built-in supervision facility of the relay e.g. relay watchdog
facility, relay self-supervision.
x.
Relay signalling & monitoring facility at local (at substation, such as HMI
(Digital Substation) and EGW) and remote (SCADA) shall be checked and
verified.
y.
Pick-up and drop-off test shall be performed for all the relays.
z.
Contact/Virtual Output Timing test shall be performed for the following output
contacts of the protection relay:Contacts initiating trip circuits
Contacts initiating breaker failure
Contacts or GOOSE Output initiating auto-reclose
Contacts or GOOSE Output initiating digital fault recorders
Contacts or MMS Output initiating HMI (Digital Substation)/EGW/SCADA
Both the pick-up and reset delay time shall be measured during the contact timing
test.
aa. For relays with any of the following functions, the function shall be tested and
documented.
! "#
$ $
Built-in instrument or metering function
Built-in event recorders.
Built-in fault recorders.
bb. DC Fail simulation shall be performed to confirm IRF indication and relay does
not trip during DC interruption (e.g. after DC recover and when relay is
rebooting)
cc. Any equipment failure detected during SAT shall be recorded in (Product
Issue Notification / Product Submission for Investigation) form as attached and
report to TNB to initiate equipment root cause analysis process.
3.0 Protection and Control functions
The following secondary injection tests shall be performed based on the general requirements of
Section 2.0 of this Appendix I.
3.1 Line
Differential
Protection
Function
The following secondary injection tests shall be performed:
a. At least the following secondary injection test shall be performed, to ensure
the relay operates only for its intended function and not otherwise:
All phase to phase fault
All phase to ground fault
Three phase fault
Trip (5 x Pick Up setting) and timing test
Communication fail test
b. DC Fail
3.2 Pilot Wire
Protection
Function
The following secondary injection tests shall be performed :
a.
At least the following secondary injection tests shall be performed, to ensure
the relay operates only for its intended function and not otherwise.
i. All phase to phase fault
ii. All phase to ground fault
iii. Three phase
b.
OC Check pick up and timing test to be tested.
c.
Pilot wire Intertrip via external initiation to be tested.
d.
To check measured loop resistance and test supervision function.
e.
DC Fail
&
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$ $
The following secondary injection tests shall be performed:
3.3 Distance
Protection
Function
a.
At least the following secondary injection test shall be performed irrespective
of whether the function is used or switched off:
i.
Reach test for forward and reverse direction for Zone 1, Zone 2, Zone 3,
Zone 3R (where applicable) and starting Zone for the R-N, Y-N, B-N, RY, Y-B, B-R and RYB faults. This test shall be done at 10-degree line
angle interval for the two forward and reverse quadrants.
ii.
Perform output contact operating for all type of faults in Zone 1, Zone 2,
Zone Aided (where applicable), Zone 3 and Zone 3R (where applicable).
Timing shall be measured at line angle at 80% of each Zone reach
(avoiding boundary)
iii. Test Directional Earth Fault (DEF) Feature if applicable. All following
tests shall be carried out for R-N, Y-N and B-N faults:
• DEF directional
• DEF carrier send time
• DEF trip time
• DEF echo time
iv. Test the VT supervision feature (Pickup/Drop off and alarm timing)
v.
Test the VT MCB blocking feature
vi. Test the SOTF feature where applicable
vii. DC Fail
3.4 Autoreclose
and
Synchronizing
Check Function
The following secondary injection tests shall be performed:
a. At least the following functions of the relay shall be tested:
AR pick up for dead time and reclaim time
Synchronising pick up test for angle setting, frequency setting and
voltage difference
To verify voltage status at 15% (dead status), 50% (undefined status) and
85% (live status) of the incoming input voltage.
To verify voltage status at 15% (dead status), 50% (undefined status) and
85% (live status) of the running input voltage
b. To verify Synchronizing and Voltage check function :
•
Dead Line/Dead Bus (DL/DB) scheme
•
Live Line/Dead Bus (LL/DB) scheme
•
Dead Line/Live Bus (DL/LB) scheme
•
Live Line/Live Bus (LL/LB) scheme
c.
To verify Voltage Check blocking
d. DC Fail
"
! "#
$ $
The following secondary injection tests shall be performed:
3.5 Thermal
Overload
Function
a. At least the following functions of the relay shall be tested:
Pick Up
Stage 1 THOL timing test for alarm
b. DC Fail
3.6Transformer/
Reactor Bias
Differential
Protection
Function
The following secondary injection tests shall be performed:
a. At least the following secondary injection tests shall be performed:
i. All phase to phase fault (for all windings i.e. HV, LV, tertiary)
ii. All phase to ground fault (for all windings i.e. HV, LV, tertiary)
iii. Operation and restraint with timing test
iv. Un-restraint test (where applicable)
v. Second harmonic restraintt and cross blocking function
vi. Full Load Relay Secondary Stability Test (HV-LV)
vii. Overflux stage 1 (alarm) and stage 2 (tripping) Test (when applicable)
b. DC Fail
'
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$ $
3.7 Transformer
/ Reactor High
Impedance
Protection and
Restricted Earth
Fault Function
The following secondary injection tests shall be performed:
a. The following setting calculation shall be done before testing
i.
Measurement of pilot loop resistance (Lead + CT resistance) for all
feeders
ii. This reading should be recorded in the resistive diagram.
iii. Calculation of stabilizing voltage and resistor
iv. Setting of stabilizing resistor.
b. Set the relay accordingly
d. High impedance voltage or current operated relay, the point of injection for
relay voltage setting tests shall be across the relay and stabilizing resistance
or metrosil where applicable. Both operating voltage and current shall be
recorded.
e. All typ of phase to ground secondary injection test shall be performed.
f.
Record the measured value and verify with the calculated setting and ohmic
value.
Voltage drop across and current into the high impedance scheme (relay
and resistor)
Total IPOC (primary operating current). Injection to be performed without
CT circuit isolated to allow CT magnetizing current to be included
g. DC Fail
3.8 Overcurrent
Protection
Function
The following secondary injection tests shall be performed: a.
At least the following secondary injection tests shall be performed, to ensure
the relay operates only for its intended function and not otherwise.
i.
ii.
iii.
iv.
OC/EF Start
OC IDMT
EF IDMT
TCS (Trip circuit supervision – where applicable, usually at 33kV and
below)
v. CBF (Circuit breaker failure alarm – where applicable, usually at 33kV
and below)
c.
Only characteristic type e.g. IDMT NI, EI and DT (for Capbank) used to be
tested. Example; for an Overcurrent relay with IDMT normal inverse setting
and set for phase fault only, only OC IDMT shall be performed.
d.
DC Fail
(
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$ $
The following secondary injection tests shall be performed:
3.9 Standby
Earth Fault
Protection
Function
a.
At least the following secondary injection test shall be performed, to ensure
the relay operates only for its intended function and not otherwise:
SBEF element pick up
All the timer stage
b.
3.10 Busbar and
Stub High
Impedance
Protection
Function
DC Fail
The following secondary injection tests shall be performed to test the following
relays:
Check-Zone high impedance relay
All discriminative Zone high impedance relay
CT supervision relay (where applicable)
a. The following setting calculation shall be done before testing:
i.
Measurement of pilot loop resistance (Lead + CT resistance) for all
feeders
ii. This reading should be recorded in the resistive diagram.
iii. Calculation of stabilizing voltage and resistor
iv. Setting of stabilizing resistor.
v. Calculation of CT Supervision relay setting
b. Set the relay and CT Supervision relay accordingly
c.
High impedance voltage or current operated relay, the point of injection for
relay voltage setting tests shall be across the relay and stabilizing resistance
or metrosil where applicable. Both operating voltage and current shall be
recorded.
d. Record the measured voltage drop across and current into the high
impedance scheme and verify with the calculated setting and ohmic value.
e. For CT supervision relays timer and pick up to be tested.
f.
Record the measured value and verify with the calculated setting and ohmic
value.
Voltage drop across and current into the high impedance scheme (relay
and resistor)
Total IPOC (primary operating current). Injection to be performed without
CT circuit isolated to allow CT magnetizing current to be included
g. DC Fail
)
! "#
$ $
The following secondary injection tests shall be performed:
3.11 Low
Impedance
Busbar
Protection
Function
a. All tests recommended by the relay manufacturer.
b. At least the following secondary injection test shall be performed:
Injection at each feeder (Bay Unit) to validate CT ratio and measurement
Injection at selected feeder (Bay Unit) to validate relay pick up, drop off
and operation time for each Zone
Verify substation topology. Confirm correct busbar Zone operation
CT Supervision blocking function, pick up, drop off, timer and alarm
c.
DC Fail
The following secondary injection tests shall be performed:
3.12 Breaker
Failure
Protection
a. At least the following secondary injection test shall be performed:
Verify the phase segregation for all the starting signals.
Verify the phase segregation for all the current circuits.
Verify relay pick up with both starting elements and current elements
Timing test for stage 1 and stage 2.
Verify timer reset via either removal of starting signals or current
elements.
b. DC Fail
3.13 Manual
synchronizing
Check
Protection
Function
The following secondary injection tests shall be performed:
a. At least the following functions of the relay shall be tested:
11 Synchronising pick up test for angle setting, frequency setting and voltage
difference
12 To verify voltage status at 15% (dead status), 50% (undefined status) and
85% (live status) of the incoming input voltage.
13 To verify voltage status at 15% (dead status), 50% (undefined status) and
85% (live status) of the running input voltage
b. To verify Synchronising and Voltage Check function:
•
Dead Line/Dead Bus (DL/DB) scheme
•
Live Line/Dead Bus (LL/DB) scheme
•
Dead Line/Live Bus (DL/LB) scheme
•
Live Line/Live Bus (LL/LB) scheme
c.
To verify Voltage Check blocking
d. DC Fail
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$ $
The following secondary injection tests shall be performed:
3.14
Demand/Load
Shedding
Function
a. At least the following secondary injection test shall be performed :
i.
ii.
iii.
iv.
Under frequency for all stages.
Under voltage for all stages
Timing test for all stages.
Under voltage blocking for Under frequency and Under voltage stages
Pick up shall be performed based on frequency ramping methodology with
at least 0.01Hz/s rate (1mHz at every 100ms)
Timing test shall be performed based on frequency ramping methodology
with at least 1Hz/s rate (10mHz at every 10ms)
Based on the methodology as stated above, the expected relay operation
time is about 130ms for an expected instantaneous operation.
b. DC Fail
3.15 Automated
Voltage Regulator
Function
The following secondary injection tests shall be performed:
a. At least the following secondary injection test shall be performed :
i.
ii.
iii.
Verify pick up for voltage regulation and bandwidth.
Timing tests with definite time.
Verify pick up for Over voltage/under voltage and confirm blocking for
any raise or lower operation.
Operation Mode Auto / Manual verification
• For circulating current paralleling scheme, it can be tested during
on-load
• Raise and lower for manual operation
iv.
b. CB/Isolator status check to confirm correct auxiliary contact are wired
c. Topology check as per actual system configuration. For 1HCB system,
verify the topology and Busbar Decoupling Switch is functioning as per
intended design. The Busbar Decoupling Switch shall be switched open
when all diameters are decoupled between the two busbars of the 1HCB
system and reflected correctly in the topology.
d. DC Fail
3.16 Unbalanced
Capbank
Protection
Function
The following secondary injection tests shall be performed:
a.
At least the following secondary injection test shall be performed:
i.
ii.
iii.
b. DC Fail
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Operating current pick up for all stages without taking into account
natural unbalance compensation.
Operating current pick up for all stages with the effect of natural
unbalanced compensation setting
Timing test for all stages.
The following secondary injection tests shall be performed:
3.17 Overload
Capbank
Protection
Function
a.
At least the following secondary injection tests shall be performed:
i.
ii.
iii.
b.
3.18 Under
Voltage Or Over
Voltage Capbank
Function
Pick up test for stage 1 (alarm) and stage 2 (trip)
Timing test for stage 1 with Definite time
Timing test for stage 2 with IDMT
DC Fail
The following secondary injection tests shall be performed:
a.
At least the following secondary injection tests shall be performed,.
i.
ii.
iii.
3.19 Point of
Wave Controller
3.20 Earth Switch
Under Voltage
Function
Pick up test for all stages under and over voltage
Timing test on under voltage stage 1 with Definite time
Timing test on over voltage stage 1 and 2 with Definite time
b.
DC Fail
c.
To verify CB Open condition does inhibit undervoltage function
The following secondary injection tests shall be performed:
a.
To verify correct point of wave switching, test shall be carried out by
current or voltage injection. For reactor, verify CB opening at zero current
crossing and for capacitor, verify CB closing at zero voltage crossing and
CB opening at maximum voltage.
b.
For 132kV ungrounded capacitor, it is expected 2 poles closing (e.g. Y and
B pole) during phase-phase voltage crossing (e.g. Y-B) and followed by
last pole (e.g R pole) after 5ms. For 275kV grounded capacitor, the 1-pole
operated CB closing shall be verified at each phase zero voltage crossing.
c.
For 132kV ungrounded capacitor, it is expected 1 pole opening (e.g. R
pole) at phase voltage maximum (e.g R ph when current is almost zero)
and followed by two other phases (e.g Y-B pole) opening during phasephase) voltage crossing (e.g Y-B ph after 5ms. For 275kV capacitor, the 1pole operated CB opening shall be verified at each phase voltage
maximum.
d.
For reactor, 1-pole CB closing shall be verified at each phase zero voltage
crossing.
e.
For reactor, 1-pole CB opening shall be verified at each phase maximum
voltage crossing.
The following secondary injection tests shall be performed:
a.
At least the following secondary injection tests shall be performed,
i.
ii.
b.
Pick up test for under voltage
Timing test
DC Fail
$
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3.21 Transducers/
Meters or
Instrument Meter
(DPM) Function
The following secondary injection tests shall be performed:
a.
Calibration of indicating meters and transducers shall be done over its
complete range (if applicable).
b.
The accuracy check of transducers through secondary injection. Error
Tolerance shall refer to the Transducer class.
The following secondary injection tests shall be performed:
3.22 Input and
Output IED
•
•
•
Measurement function (Station IOIED)
Tripping function (Transformer IOIED)
Hardwiring to GOOSE signal conversion function (Station &
Transformer IOIED)
a. Verify all relays BIBO are configured as per section 2.0
b. Verify DC System
4.0 Integrated Protection and Control applications
4.1 Integrated
Line Protection
This application consists of these functions:
• Current Differential Protection (Section 3.1)
• Backup Distance Protection (Section 3.3)
• Thermal Overload (Section 3.5)
4.2 Integrated
Backup Distance
with Thermal
Overload
Protection
This application consists of these functions:
• Backup Distance Protection (Section 3.3)
• Thermal Overload (Section 3.5)
4.3 Circuit
Breaker
Management
This application consists of these functions and Scheme:
• Breaker Failure Protection (Section 3.12)
• Autoreclose and Synchronizing Check (Section 3.4)
• Overcurrent Protection for Transformer and Capbank (Section 3.8)
• Pole Discordance Scheme
4.4 Bay Controller
This application consists of these functions and Scheme:
• Switchgear Operation & Interlocking Scheme
• Manual Synchronizing Check (Section 3.13)
• Earth Switch Interlock (Section 3.20)
• Measurements (Section 3.21)
4.5 Overload and
Overcurrent
Capbank
This application consists of these functions:
• Overload function (Section 3.17)
• Overcurrent function (Section 3.8)
4.6 Overvoltage
and Undervoltage
Capbank
Station IOIED/IOIED consists of these functions and Scheme:
• Overvoltage function (Section 3.18)
• Undervoltage function (Section 3.18)
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5.0 Functional Test Guideline
The following test form for Protection Function shall be served as a guideline and be extended to
complete all the testing scope as per requirement in Section 1 to Section 4 in this document.
5.1.1 Current Differential Function: Pick Up Test
Setting Is (A)
Expected value
Differential Operation (Id>), Setting (
Actual current
Max. Allowable range
)
Allowable Error
R
±5%
Y
B
R-Y
Y-B
B-R
R-Y-B
note : Usually the tolerance or actual pick up value is based on injection condition and characteristic of the relay.
5.1.2 Current Differential Function: Timing Test
Setting Is (A)
Red
Current Injection
5A
Yellow
5A
Blue
5A
Differential Operation (Id>)
Actual time (ms)
Max. Allowable range
Allowable Error
<30ms
5.2.1 Distance Function: Reach Test
Zone
Zone 1
Zone 2
Zone 3
Fault Type
Expected Reach
(Setting)
0º
Line Angle
(Quad) or
(as per
90 º
setting)
(mho)
R-N
Y-N
B-N
R-Y
Y-B
B-R
R-Y-B
R-N
Y-N
B-N
R-Y
Y-B
B-R
R-Y-B
R-N
Y-N
B-N
R-Y
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Measured Reach
0 º (Quad)
or 90 º
(mho)
Line Angle
(as per
setting)
Max.
Allowable
range
Allowable
Error %
±5%
$ $
Zone
Fault Type
Expected Reach
(Setting)
0º
Line Angle
(Quad) or
(as per
90 º
setting)
(mho)
Measured Reach
0 º (Quad)
or 90 º
(mho)
Line Angle
(as per
setting)
Max.
Allowable
range
Allowable
Error %
Y-B
B-R
R-Y-B
R-N
Y-N
B-N
R-Y
Y-B
B-R
R-Y-B
Rever
se
Zone
5.2.2 Distance Function: Reach Test: Timing Test
Zone
Z1
Timing Setting Z1 (
), Z2 (
), Z3 (
Actual time (ms)
Max. Allowable range
R-N
Z2
Y-N
Z3
R-Y-B
Z3 Rev
Y-B
), Z3Rev (
)
Allowable Error
Setting + 10ms (contact
make time)
5.2.3 Distance Function: Reach Test: SOTF & TOR Test
1.
2.
3.
4.
Simulate TOR (Trip on Reclosing) at CBM. This test can be performed during CBM (AR) functional test
Simulate Manual closing from Bay Controller.
Verify if there is any AR initiation (CBM), M/Trip operation, Intertrip to remote end being initiated. “AR
Lock Out Intertrip” to remote end can be verified by retrieving relay event list
Normalize the system after testing
Procedure / Activity
Simulate SOTF condition as per 1 & 2 by
initiate manual closing or TOR,
simultaneously, inject R-N phase fault
AR
Operation
Master trip
operation
No AR
M/Trip
Operated
Lockout
Intertrip to
Remote End
Yes
Actual
Result
(P/F)
5.2.4 Distance Function: VTS Test
1.
2.
3.
4.
5.
Switch off C.Diff function during the test
Simulate MCB Trip (Off MCB), and observe any alarm, indication at Station HMI
Simulate MCB Trip condition and inject Z1 R-N fault
Verify if there is any relay operation
Normalize the system after testing
Procedure / Activity
Simulate MCB Trip (Off MCB), and observe
any alarm, indication etc
Relay Operation
Actual Result (P/F)
VTS operated
(Station HMI & LED)
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Procedure / Activity
Relay Operation
Actual Result (P/F)
Simulate MCB Trip condition and inject Z1 RN fault
No relay operation and
No tripping issued
5.3.1 Autoreclose Function: Pick Up Test
Setting Is (A)
Setting
Actual
Pick Up Test
Result (P/F)
Dead Time (1 Pole)
Allowable Error
Dead time should be calculated
from AR In Progress up to contact
make time = setting + 10ms
Dead Time (3 Pole)
Reclaim Time
5.3.2 Synchronizing Function: Pick Up Test
Setting Is (A)
Setting
Actual
Pick Up Test
Result (P/F)
Allowable Error
Voltage Diff ( V)
Frequency Diff (Hz)
±5%
Phase Angle Diff
( )
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$ $
5.3.3 Synchronizing Function: Voltage Check
Voltage
Check
Condition
DBLL
DLLB
DLDB
Sync
Check
DB
0
LL
>80%
VI : Line
VT Fail
(From
BCU)
N
DB
0
LL
60%
N
N
Not Allow
DB
0
LL
>80%
N
FAIL
Not Allow
DB
0
LL
>80%
N
FAIL on RBB
Allow
DB
0
LL
>80%
FAIL
N
Allow
Fix injection
VI : BB VT Fail
(MBB1), unless
specified
otherwise
N
Expected
result (BO :
CB Close )
DL
0
LB
>80%
N
N
Allow
0
LB
60%
N
N
Not Allow
DL
0
LB
>80%
FAIL
N
Not Allow
DL
0
LB
>80%
N
FAIL
Allow
DL
0
LB
0
N
N
Allow
DL
60%
DB
60%
N
N
Not Allow
DL
0
LB
0
FAIL
FAIL
Not Allow
DL
0
DB
0
FAIL
N
Not Allow
DL
0
DB
0
N
FAIL
Not Allow
LL
>80
%
>80
%
LB
>80%
N
LB
>80%
FAIL
a.
Simulate Bay under MBB1
MBB2 = 50% RBB = 70% Vn and MBB1 = 100%
Vn)
b.
Simulate Bay under MBB2
MBB1 = 50% RBB = 70% Vn and MBB2 = 100%
Vn)
c.
Simulate Bay under MBB1
MBB1 = 50% MBB2 = 70% Vn and MBB1 = 100%
Vn)
N
FAIL
(P/F)
Allow
DL
LL
Running
Voltage
Vary injection
(Voltage)
Allow
Allow
MBB1 voltage is referred
MBB2 voltage is referred
RBB voltage is referred
5.4.1 Transformer Biased Differential Function: Timing Test (Lower & Upper Slope)
Refer to relay characteristic to select injection points. As an example, for lower slope, I Diff (0.5A) with I
Biased (1A), whereas for higher slope, I Diff (1A) with I Biased (4A) can be of selection for Trip Region
Note: FAT requirement: minimum 6 tests (2 test in each phase) and shall be randomly selected by
Inspector.
DV or Routine Test requirement: all the tests (4 test in each phase) shall be completed
Phase
Region
R
Trip
Trip
Restraint
Restraint
I Diff (A)
I Biased (A)
Operating
Time
Allowable
range
Allowable
Error
PU ±5%
Operating
'
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$ $
Y
B
Trip
Trip
Restraint
Restraint
Trip
Trip
Restraint
Restraint
time <
30ms
5.4.1 Transformer Biased Differential Function: Biased Characteristic Test
Phase
Ibias
Expected
IDiff*
Actual IDiff
Allowable
Range
0.50In
2.00In
4.00In
0.50In
Y
2.00In
4.00In
0.50In
B
2.00In
4.00In
*Expected IDIFF can be obtained from Relay Characteristic Graph
Allowable
Error %
R
±5%
5.5.1 High Impedance Differential Function: Biased Characteristic Test
RELAY ACCESSORIES VERIFICATION
Verify if the accessories and connection as per design:
No Accessories
Range (Ohm)
1
External Metrosil
2
External shunt
R:
stabilizing adjustable
Y:
B:
resistor
3
External series
R:
stabilizing adjustable
Y:
resistor
B:
Connection Point
R:
Y:
B:
R:
Y:
B:
5.5.2 Hi Impedance Function : Pick Up And Timing Test
1.
2.
This testing shall be performed with a typical setting of Ipoc = 0.2A and Voltage setting of 100V.
Resistors shall be adjusted accordingly prior to testing.
Note :
If test set is not able to produce adequate current up to 0.2A, it is advisable to change to voltage
output source mode during the testing.
Voltage operated relay: Adjust Shunt stabilizing resistor until total injection current reach around
0.2A.
Current operated relay: Set relay to operate at 0.2A. Adjust series stabilizing resistor until voltage
across relay and series resistor is about 100v.
Record all the result: Actual Injection Current (Primary Operating Current), voltage across relay
scheme (relay + series resistor if any), adjusted resistor value, and operating time.
(
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Phase
Operating
Time
Current
IPOC
Voltage across relay
scheme (relay +
series Resistor if any)
Resistor value
Rseries
Error %
Ipoc
Rshunt
R
PU ±5%
Y
Operati
ng time
< 30ms
B
)
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$ $
SAT Appendix J: SAT for Primary Equipment
1.0
2.0
3.0
4.0
5.0
6.0
7.0
8.0
9.0
10.0
11.0
12.0
13.0
14.0
15.0
16.0
17.0
18.0
Purpose .................................................................................................................................... 2
General Requirement ............................................................................................................... 2
Circuit Breaker Testing ............................................................................................................ 4
Gas Insulated Substation (GIS) ............................................................................................... 7
Power Transformer (Applicable for 132kV and Above) ......................................................... 12
Earthing Transformer Testing ................................................................................................ 18
Neutral Earthing Resistor (NER) Testing ............................................................................... 21
Disconnector Testing ............................................................................................................. 23
Current Transformer Testing.................................................................................................. 25
Voltage Transformer Testing (Capacitive / Inductive) ........................................................... 28
Capacitor Bank Testing.......................................................................................................... 31
Surge Arrestor Testing ........................................................................................................... 33
Sealing End Testing ............................................................................................................... 35
Reactor (Oil Immersed Type) Testing .................................................................................... 36
Reactor (Dry Type) Testing.................................................................................................... 39
Switchyard Installations Testing ............................................................................................ 40
11kV and 33kV Switchgear Testing ....................................................................................... 42
Standby Diesel Engine Driven Generator………………………………………………………..47
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1.0
Purpose
2.0
General
Requirement
To provide SAT requirements when carrying out Primary Equipment tests
.
a. All tests to be carried out together with those listed in the contract
specification.
b. All tests for primary equipment shall be completed under stage 2 (Appendix S
flowchart) unless specified otherwise.
c. All primary equipment shall be checked in accordance with Nameplate Rating
and Contractual Technical Specification.
d. All inspections, checks and tests carried out shall be recorded.
e. All alarms for primary equipment shall be tested by actual simulation unless
specified otherwise or no facilities provided.
f. All bolts and nuts shall be torqued accordingly checked and to be free from rust.
g. All equipment installed shall be checked to have minimum safety, electrical and
ground clearances.
h. All the cubicle doors, marshalling kiosks and panels shall be checked and proven
to be vermin and moisture proof, and properly ventilated and having locking
facility.
i. All the components of the equipment shall be checked to function and operate as
intended.
j. All the bushings and insulators shall be checked and to be free from cracks / chip
off and deposits.
k. All installation of primary equipment shall be in accordance with the approved
drawings and installation instruction by the manufacturer.
l. All related primary equipment operation & maintenance manuals shall be made
available on-site prior to the commencement of Site Acceptance Test (SAT).
These shall include but not limited to:
i.
Equipment O&M
ii.
Site Drawings approved by TNB
iii.
Factory Acceptance Test Results.
iv.
Contract Specifications.
m. Contractors to ensure that inspections, testing and commissioning shall be
carried out by competent, certified and/or qualified person.
n. All primary equipment shall be earthed in accordance with the approved earthing
design.
o. Check of the completeness, correctness and condition of earth connections,
labelling, clearances, painted surfaces, cables, wiring, pipework, valves, blanking
plates and all other auxiliary and ancillary items.
p. Checks for no sign of (insulation medium) system leak.
q. Spares and loose items to be handed over shall be listed, checked and correctly
stored e.g. blanking plates, special tools, etc.
$
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r. All recommended values, tolerances and tested values to be recorded.
s. All equipment to be locked upon completion of SAT and prior to commissioning.
t. Cleanliness checks shall be performed.
u. Tests listed shall be applicable for all voltage levels unless specified otherwise.
v. All equipment with Online Monitoring System (OMS) shall be tested (but not
limited) as follows: i.
Check for physical condition – i.e. leaking, any physical defects.
ii.
Cabling tray, test tap connection for bushing monitoring.
iii.
Operational test i.e. alarm indication, system healthiness.
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3.0
Circuit Breaker Testing
3.1
Test Form
Requirement
a. All general information as required in Appendix A.
b. At least the following details of the switchgear shall be mentioned in test sheet:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
3.2
Testing
Required
Circuit Breaker make
Circuit Breaker type
Operating medium
Insulating medium pressure
Rated nominal, short circuit current
Operating sequence
Basic Insulation Level (BIL)
Serial No.
Rated Voltage
Date of manufacture
a. All testing required/recommended by the manufacturer of the switchgear and its
accessories shall be conducted and recorded clearly in the test form.
b. In addition, the following physical check shall include but not limited to:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
xi.
xii.
xiii.
xiv.
xv.
xvi.
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To check for insulation medium leaks
Checks for any corrosion, damage or defect
Tightness of connections using correct torque
Insulator bushings checks for cracks
Earthing connection
Wire and cable connections
Cable entrance to control cubicle shall be from bottom, sealed and water
and vermin proof
Heaters and lamps in working order
Ensure recommended thermostat temperature setting label is available
inside the control cubicle.
Check for linkages connection between poles and mechanism.
Lubrication and grease for gears and linkages.
Gauges shall be visible, leakage, upper/lower limit.
Check SF6 Piping installed properly (dents and welding point).
Check valve in operation position (where applicable).
Locking facilities for mechanism / CB box.
Labeling for CB Mechanism Box.
c.
The following electrical test on the equipment shall include but not limited to:
No
Test
Details
Limit
1
Contact
resistance
test
• Shall be carried
out for all phases
• Test point shall be
as close as
possible to the CB
contacts unless
recommended
otherwise by
manufacturer.
• Based on factory
routine test result/
O&M
• Within
manufacture’s
recommended /
tolerance value as
prescribed in
Routine test / FAT
• Shall be consistent
for all phases.
2
Timing test
For all phases:
• Close and trip
timing
• C-O operation
• Synchronism
between the main
contact in the
three phases
• Timing on main
contact on each
pole (for 275kV,
500kV &
Capbank)
•
•
•
•
•
Based on factory
routine test result/
O & M.
Within
manufacture’s
recommended /
tolerance value as
prescribed in
Routine test / FAT
Pole spread shall
be <5ms
To follow O&M
proposed limit
No contact
bouncing detected
3
Insulation
resistance
test
Applying 5 kV DC
using insulation tester
for insulator and
conductor to earth
• More than 1G
• Shall be consistent
for all phases.
4
Close open
operation
For all type of CB
• Motor run time
from start of motor
to motor stop
Within recommended
manufacture’s tolerance
as prescribed in factory
test
5
Auto reclose
operation
•
Within recommended
manufacture’s tolerance
as prescribed in factory
test
Determine A/R
block (CB ready)
signal presence at
A/R relay
&
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$ $
6
SF6
Pressure
To do actual operation
of SF6 leakage with
series connection for
Stage 1 & 2 :
Stage 1- Alarm
Stage 2 – Trip &
Lockout
Within recommended
manufacture’s tolerance
as prescribed in factory
test
For Generator Feeder
with series connection
for Stage 1 & 2:
Stage 1- Alarm
Stage 2 – Lockin
d. The following are Insulating medium (SF6) – IEC 60376/ IEC 60480 test shall
include but not limited to:
No
1
Test
Details
Moisture Content SF6 dew point test
2
SF6 purity test
3
S02 content
To check composition
of SF6 gas
To check present of
SO2 in SF6.
Limit
< -300C @ ATM (46
ppm-mass)
> 97%
< 12ppmv
* OEM has to clarify should there be a ±10% variance in the SF6 gas value tested prior
to commissioning and 8 months after commissioning.
e. Operation, indication and interlock test shall be carried out:
i.
ii.
iii.
iv.
v.
vi.
vii.
Inspection on the wiring, position indicators, auxiliary switches,
terminal blocks and components e.g. Labeling, tightness, colour
coding.
Manual operation of switchgear shall be conducted e.g. slow closing,
manual spring charging, manual tripping, etc
Operational tests shall be carried out on the operating mechanism
system and the SF6 monitoring system.
All recommended values and tested values to be recorded e.g.
duration, switches/protection setting, gauges reading and counter
reading
Control and operation tests to be carried out e.g. control, protection,
alarm and indications circuit
All indications related to the equipment to be tested and proven
working
Checks and operation shall be made on the Interlocks and safety
features e.g. electrical and mechanical interlocks and safety valves
"
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4.0
Gas Insulated Substation (GIS)
4.1
Test Form
Requirement
a. All general information as required in Appendix A.
b. At least the following details of the GIS shall be mentioned:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
4.2
Testing
Required
Rated voltage
Rated current
Equipment model
Operating mechanism
Serial number
Date of manufacture
Bay/Compartment involved
Short circuit rating
Following are the tests required to pre-commission the GIS:
a. All testing required/recommended by the manufacturer of the GIS and its
accessories shall be conducted and recorded clearly in the test form.
b. In addition, all the following physical check/inspection shall also be conducted
and recorded clearly in the test form.
i.
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
Tightness of connections using correct torque
Insulator bushings checks for cracks
Earthing connection
Wire and cable connections
Cable entrance to control cubicle shall be from bottom, sealed and water
and vermin proof
Heaters and lamps in working order
Ensure recommended thermostat temperature setting label is available
inside the control cubicle
Earth switch indication
To check GIS/GIB enclosure is clean and free from fungus.
Locking facilities.
To do actual calibration test to verify SF6 gauge pressure is accurate.
c. The following are electrical test to be carried out:
No
1
Test
Disconnectors
and Circuit
Breaker Contact
resistance test
Details
Limit
• Based on factory
• Shall be carried
routine test result/
out for all phases
O&M
• Test point shall
be as close as
• Within recommended
manufacture’s
possible to the
tolerance as prescribed
CB contacts
in factory test
unless
recommended
• Shall be consistent for
otherwise by
all phases.
manufacturer.
• Disconnectors to
be tested if
facility permit.
'
! "#
$ $
2
Timing test
For all phases:
• Close and trip
timing
• C-O operation
• Synchronism
between the
main contact in
the three
phases
• Timing on main
contact on each
pole (275kV &
Capacitor bank)
•
•
•
•
Based on factory
routine test result/
O&M.
Within recommended
manufacture’s
tolerance as
prescribed in factory
test
Pole spread shall be
<5ms
To follow O&M
proposed limit
3
Insulation
resistance test
Applying 5 kV DC
using insulation
tester for insulator
and conductor to
earth
•
•
4
Close open
operation
For all type of CB
• Motor run time
from start of
motor to motor
stop
Within recommended
manufacture’s tolerance
as prescribed in factory
test
> 1G
Shall be consistent for
all phases.
For hydraulic CB
• Motor start
pressure
• Motor stop
pressure
• Alarm stage
pressure
• Trip stage
pressure
• (Actual pressure
release)
5
Auto-reclose
operation
For hydraulic CB
• Manually openclose-open (o-co) sequence
and record
pressure
• Determine A/R
block (CB
ready) signal
presence at A/R
relay
Within recommended
manufacture’s tolerance
as prescribed in factory
test
(
! "#
$ $
6
SF6 Pressure
To do actual
operation of SF6
leakage with series
connection for Stage
1 & 2:
Within recommended
manufacture’s tolerance
as prescribed in factory
test
Circuit Breaker /
Line Disconnectors
Stage 1- Alarm
Stage 2 - Trip &
Lockout
Busbar Disconnector
Stage 1- Alarm
Stage 2- Lockin
d. The following tests (8&9) are to be carried out after completion of the above
tests and all other pre-commissioning tests prior to commissioning.
No
8
Test
Short duration
power frequency
withstand voltage
test to be
performed phase
by phase
Details
132 kV GIS:
Able to withstand 235kV
RMS for 1 min
Limit
Based on IEC 62271203.
275 kV GIS:
Able to withstand 380kV
RMS for 1 min
**Conditioning to be
performed phase by
phase as per OEM
requirement
)
! "#
$ $
9
Partial discharge
measurement to be
performed phase
by phase by the
preferred UHF
method.
This test should be
conducted after test no
8. This is to ensure all
particles will be active
and can be detected
after HV test
Acoustic method
shall be used only
when GIS
construction does
not have epoxy
spacer.
132 kV PD test voltage
(phase to earth):
• 101kV rms
(1.2xrated
voltage/ 3)
Based on IEC 62271203 and IEC 60270.
For PD measurement
Maximum allowable
Discharge 10pC
measured by
Conventional or UHF.
For acoustic
measurement no
discharge should be
detected.
275 kV PD test voltage
(phase to earth):
• 208kV rms (1.2 x
rated voltage/
3)
During short duration power frequency withstand voltage test, the Voltage
Transformer, Surge Arrester and Power Cable to be isolated.
e. Following are the test required for GIS insulating medium (SF6) – IEC 60376 &
IEC 60480. This test shall be conducted after all electrical test.
No
1
Test
Moisture
Content
Details
SF6 dew point test
Limit
CB compartment:
< -30oC @ATM
(46 ppm-mass)
*For Toshiba &
Hitachi make;
< -36oC @ATM
(24 ppm-mass)
Other compartment:
< -27oC @ATM
(63 ppm-mass)
2
3
! "#
$ $
SF6 purity test
SO2 Content
* For Toshiba &
Hitachi make;
< -30oC @ATM
(46 ppm-mass)
To check composition of > 97%
SF6 gas at every
compartment
To check SO2 content
inside each
compartment
< 12ppmv
* OEM has to clarify should there be a ±10% variance in the SF6 gas value tested prior
to commissioning and 8 months after commissioning.
For GIB / Cable box compartment the above test shall be conducted after
connection to transformer / cable.
f.
The following operation, indication and interlock test shall be done but not
limited to:
i.
ii.
iii.
iv.
v.
vi.
vii.
Inspections on the wiring, position indicators, auxiliary switches, terminal
blocks and components e.g. labelling, tightness, colour coding.
Manual operation of switchgear shall be conducted e.g. slow closing,
manual spring charging, and manual tripping.
Operational Tests shall be carried out on the spring/hydraulic operating
system and the SF6 monitoring system.
All recommended values and tested values to be recorded e.g. Duration,
switches/protection setting, gauges reading and counter readings.
Control and operation tests to be carried out e.g. Control, protection, alarm
and indications circuit.
All indications related to the equipment to be tested and proven working.
Checks and operation shall be made on the Interlocks and safety features
e.g. electrical and mechanical interlocks and safety valves.
g. Online Monitoring System (OMS) – If applicable
i.
ii.
iii.
! "#
$ $
Check for physical condition – i.e. leaking, any physical defects.
Cabling tray, test tap connection for bushing monitoring.
Operational test i.e. alarm indication, system healthiness.
5.0
Power Transformer (Applicable for 132kV and Above)
a. All general information as required in Appendix A shall be provided.
5.1
Test Form
Requirement
b. At least the following details of the power transformer shall be mentioned.
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
xi.
5.2
Testing
Required
Transformer make
Transformer type
Vector Group
Capacity
Impedance
Ratio
Serial No
Rated Voltage
Date of manufacture
Short Circuit Rating
OLTC Data
Following are the test required to pre-commission the power transformer:
a. All testing required/recommended by the manufacturer of the power transformer and its
accessories shall be conducted and recorded clearly in the test form.
b. In addition, all the following physical check shall also be conducted and recorded
clearly in the test form:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
xi.
xii.
xiii.
xiv.
xv.
xvi.
xvii.
xviii.
xix.
xx.
c.
Check for any corrosion, damage or defect
Co-coordinating gaps (alignment and gap measurement)
Check for insulation leaking
Labeling e.g. valve, transformer numbering etc.
Earth connections
Explosion vent / pressure relief device, bucholz relay for main and OLTC tank.
SA/CVT droppers’ connection not to have branch connection.
Breathers (properly inspect for leaks, silica gel, etc.)
Valves in operational positions (to be checked during erection of transformer)
Correct oil levels in main tank & OLTC conservator, oil pocket, cable box and
bushing.
Safety clearances as per approved drawing
Ensure all terminal blocks, oil level gauges and other accessories including
marshalling kiosks are fully sealed/moisture and vermin proof.
All additional special equipment (e.g. Transformer explosion prevention system/
RPR) to be checked and tested.
For Auto transformer tertiary winding, to check 1 phase earth connection are
done.
Plinth check shall be within required specification
Locking facilities for valve and ladder
Ladder – Anti climbing Device
Housing for PRD, Bucholz and OLTC Surge Relay available
Bushing test plug- no moisture ingress, no damage on the tread, cover intact.
Gas collecting device for conservator air bag.
The following electrical tests shall be conducted and recorded clearly in the test
forms. The test value(s) shall conform to the limits specified below:
$
! "#
$ $
No
1
Test
Insulation resistance
Details
The test shall be performed
using a 5 kV insulation tester
at 1 min. The following
measurement shall be
recorded: 1. Between Primary and
Earth
2. Between Secondary
and Earth
3. Between Primary and
Secondary
4. Between Tertiary and
Earth
Ratio of HV: LV windings.
2
Turns Ratio
3
Vector Group
Vector Group of the
transformer
4
Winding resistance
(DC)
Measurements of winding
resistance for
i)
ii)
5
Excitation Current
HV – All tap positions
LV – Nominal tap
position
Measurements of excitation
current for all phases at 10kV
Note: Tx should not be
magnetize
Limit
> 1 GΩ @ 20°C
Within +0.5% of
nameplate ratio at all
taps.
Vector diagram
obtained from
measurement shall
be the same with
manufacturer’s
vector diagram.
1. Within 2% of
factory
measurements
after insulation
temp correction.
2. Within +5%
between phases
after correction
to 75°C
3. No break during
tap changer
operation.
1. 3 phase Tx
pattern of 2
higher currents
on the outer
phase together
with a lower
current on the
center phase.
2. 1 phase Tx
values must be
consistent for all
phase
3. Difference
between R & B
phase shall be <
10%
4. Single phase
transformer
values must be
within 10% for all
phases (same
manufacturer)
%
! "#
$ $
6.
Verification of the
fan operation, pump
operation, alarm and
trip settings of OTI
and WTI
For OTI temperature shall be
raised to the relevant settings
and verification made.
For WTI temperature shall be
raised and full load secondary
current shall be injected at the
bushing CT to the relevant
setting and verification made.
Factory test results/O
& M.
Within recommended
manufacturer’s
tolerance as
prescribed in factory
test
During this test temperature
meters installed on the RTCC
panel shall also be checked.
For pump and fan operation
shall be raised to the relevant
settings and verification made.
7.
8.
Winding Power
Factor
(See Note 1)
Bushing Power
Factor
(See Note 1)
Refer to setting table N1(a)
Measurement of Power Factor
of windings.
Correction factor to follow IEEE
C57.12/90 – 1995
Measurement of Power Factor
of all bushings
Correction factor to follow IEEE
C57.12/90 – 1995
<0.5% at 20°C
For C1:
1. < 0.7%.
2. Power factor for all
three phases <100%
difference between
phases.
∗ For any bushing
where the power
factor difference
exceeds 100%, to
be replaced.
For C2:
1. C2 bushing power
factor < 5%
9.
10
! "#
Dielectric Response
on Winding (CHL)
(See Note 1)
Oil Power Factor
(See Note 1)
$ $
% by Dry weight of Moisture
Content in Solid Insulation
Measurement of Power Factor
of Tx Oil
Correction factor to follow IEEE
C57.12/90 – 1995
Capacitance change
+5% from FAT result
< 1.0% (% moisture
content by dry
weight)
< 0.1% at 20°C
11.
Sweep Frequency
Response Analysis
(SFRA)
(See Note 1)
Measurement of the Winding
movement of the transformer.
12.
Insulation
Resistance
(Winding)
(See Note 1)
Insulation Core Resistance Earth
Core at 20°C
Frame
(Core &
Frame)
Frame (See Note Earth
1)
Leakage Reactance
(See Note 1)
Insulation resistance
measurement of the winding
13.
14.
15.
Polarization Index
*PI test not
applicable for oil
based
transformers.
Insulation resistance
measurement of the core
1. Pattern for all
phases overlapping
each other except
yellow phase slightly
lower at frequency
between 100kHz to
1kHz.
2. Same pattern
when compared with
FAT result or sister
unit.
IR at 1 minute > 1G
IR at 1 minute > 1G
IR at 1 minute > 1G
IR at 1 minute >
100M
Leakage reactance
measurements are performed
by short-circuiting the low
voltage winding. This test also
named as short circuit
impedance test.
The results must
within 3% of the
nameplate values.
The test shall be performed
using a 5 kV insulation tester.
The following measurement
shall be recorded: 1. Between Primary and
Earth
2. Between Secondary
and Earth
3. Between Primary and
Secondary
4. Between Tertiary and
Earth
> 1.2 (R10/R1min)
Note 1:
These test shall be carried out by TNB in the presence of the contractor. The
contractor shall assist in preparing the transformer for this test.
Oil and Winding Setting for Power Transformer
ONAN/ONAF
STAGE 1 - FANS
STAGE 2 - FANS (WHERE
USED)
STAGE 1 - ALARMS
STAGE 2 - TRIPS
OTI(TOP
OIL ) ON 0C
OTI(TOP
OIL ) OFF 0C
WINDING
(HOT SPOT)
ON 0C
65
55
70
WINDING
(HOT
SPOT)
OFF 0C
60
70
60
75
65
90
105
80
95
95
120
85
110
&
! "#
$ $
ONAN/ODAN/ODAF
OTI(TOP
OIL ) ON 0C
OTI(TOP
OIL ) OFF 0C
WINDING
(HOT SPOT)
ON 0C
65
70
90
105
55
60
80
95
70
75
95
120
STAGE 1 - PUMPS
STAGE 2 - FANS
STAGE 1 - ALARMS
STAGE 2 - TRIPS
Table N1(a)
WINDING
(HOT
SPOT)
OFF 0C
60
65
85
110
d. All Automatic Voltage Regulating (AVR) Relay shall be tested as in Appendix M.
e. For the transformer oil, PM shall ensure that the following tests are conducted on the
sample of oil for all compartment (Main tank, cable box, OLTC) sent for laboratory test
and recorded clearly in the test form. The following are the test required for the
transformer insulating oil. The test value(s) shall conform to the limits specified below:
No
1
Property
Absolute Moisture
Content in ppm (Not
temperature
corrected)
Limits
Highest Voltage for
Equipment (kV)
72.5 –
>170
170
< 10
≤ 0.03
≤ 0.03
IEC 422
Min 40
Min 40
IEC 422
IEC 422
Acidity (mg KOH/g)
3
Interfacial Tension
(mN/m)
4
Colour
≤ 2.0
≤ 2.0
5
Dielectric
Dissipation Factor at
90°C
Max
0.015
Max 0.015
Density Test
7
Inhibitor Content
8
Electric Strength, kV
(breakdown voltage)
IEC 422
< 10
2
6
Test Standard
IEC 422
Max
0.895
g/ml
Max 0.895
g/ml
IEC 296
Not
detected
Not
detected
-
> 60
> 60
IEC 422
10
Polybuthene oil test
for cable box
Max 60mg/kg
IEC 60963
11
Carbon content
Cp (Paraffinic Content<50%) – Naphthenic Oil.
"
! "#
$ $
f.
The following mechanical test shall be conducted and recorded clearly in the test form.
The test value(s) shall conform to the requirements specified below:
No
1
Test
Oil leak test
Condition
The transformer shall be able to withstand a
pressure of 30 kPa / 0.3 Bar from the top of
conservator filled with oil for 24 hours with no oil
leakage and no permanent deformation on the
structure.
g. The following functional test/check shall be conducted and recorded clearly in the test
form:
i.
ii.
iii.
iv.
Transformer guard check – all alarm, indication, flags, facia and relay operation at
transformer, relay panel and control panel shall be recorded clearly. Actual
operation for each signal of all transformer guards shall also be checked and
mentioned except for PRD. PRD functional check shall be conducted by
simulation.
Oil level indicator shall be functional. Oil Level (if any) shall be within permissible
range.
Pressure gauges shall be check to be functional. (if applicable)
All temperature indicators shall be operational.
v.
OLTC Check
The OLTC shall be check to be operational for:
a) Step by step
b) Out of step
c) Transformer paralleling scheme check
d) Individual Oil Filter (where applicable)
vi.
Cooler control check
The cooler operation and indications which comprise of pumps and fans shall be
checked for the following status:
a) Local b) Auto c) Remote
The time delay between pumps operation (where applicable) shall be more than 3
sec.
vii.
To ensure/verify transformer guard relays contacts making or not.
'
! "#
$ $
6.0
Earthing Transformer Testing
6.1
Test Form
Requirement
a. All general information as required in Appendix A.
b. At least the following details of the switchgear shall be mentioned:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
6.2
Testing
Required
EarthingTransformer make
Earthing Transformer type
Vector Group
Capacity
Impedance
Ratio
Serial No
Rated Voltage
Date of manufacture
Short Circuit Rating
Following are the test required to pre-commission the earthing transformer:
a. All testing required/recommended by the manufacturer of the earthing
transformer and its accessories shall be conducted and recorded clearly in the
test form.
b. In addition, all the following physical check shall also be conducted and
recorded clearly in the test form.
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
xi.
c.
Check for any corrosion, damage or defect
Co-coordinating gaps (alignment and gap measurement) where applicable
Labeling or nameplate.
Earth connections
Explosion vent / pressure relief device
Bucholz relay
Breathers (properly inspect for leaks, silica gel and etc.)
Valves in operational positions
Correct oil levels in main tank conservator
Missing components
Ensure all terminal blocks, oil level gauges and other accessories are fully
sealed/moisture and vermin proof
The following electrical test shall be conducted and recorded clearly in the
form. The test value(s) shall conform to the limits specified below.
No
Test
1
Insulation
resistance
Details
The test shall be performed
using an insulation tester. The
following measurement shall be
recorded: 1. Between Primary and
Earth (5 kV)
2. Between Secondary and
Earth (1 kV)
3. Between Primary and
Secondary (5 kV)
Limit
IR at 1 minute >
1G .
(
! "#
$ $
2
Turns Ratio
Ratio of HV: LV windings
3
Impedance
Voltage
Winding
resistance (DC)
% Measurement of zero and
positive sequence impedance
Measurements of winding
resistance at all tap positions
5
Winding Power
Factor
(See Note 1)
6
Oil Power
Factor
(See Note 1)
7
Vector Group
Measurement of Power Factor of
windings.
Correction factor to follow IEEE
C57.12/90 – 1995
Measurement of Power Factor of
Oil.
Correction factor to follow IEEE
C57.12/90 – 1995
Vector Group of the transformer
8
Polarization
Index
4
*PI test not
applicable for
oil based
transformers.
The test shall be performed
using a 5 kV insulation tester.
The following measurement shall
be recorded: 5. Between Primary and
Earth
6. Between Secondary and
Earth
7. Between Primary and
Secondary
8. Between Tertiary and
Earth
Within 0.5% of
nameplate ratio
of the rated
voltage.
+2% of FAT
Within +5%
between phases
after correction
to 75oC
< 0.5% at 20°C
< 0.1% at 20°C
Vector diagram
obtained from
measurement
shall be equal
with
manufacturer’s
vector diagram.
> 1.2
(R10/R1min)
Note 1:
This test shall be carried out by TNB in the presence of the contractor. The
contractor shall assist in preparing the transformer for this test.
d. PM to ensure transformer insulating oil test are conducted on the sample of oil
sent for laboratory test. The value(s) shall conform to the limits specified below:
No
1
2
3
Property
Absolute Water
Content in ppm
(Not temperature
corrected)
Neutralization
Value (mg KOH/g)
Interfacial
Tension (mN/m)
Limit
Highest Voltage for
Equipment
(≤ 72.5 kV)
Test Standard
< 10
IEC 422
Max 0.03
IEC 422
Min 40
IEC 422
)
! "#
$ $
4
Color
5
Electric strength,
kV (breakdown
voltage)
6
Dielectric
Dissipation Factor
at 90°C
Max 2.0
IEC 422
> 60
IEC 422
Max 0.015
e. The following functional test/check shall be conducted and recorded clearly in
the test form.
i.
Transformer guard check – all alarm, indication, flags, fascia and relay
operation at transformer, relay panel and control panel shall be recorded
clearly. Actual operation for each signal of all earthing transformer guards
shall also be checked and mentioned except for PRD. PRD functional check
shall be conducted by simulation.
ii. Oil level indicator shall be functional. Oil Level (if any) shall be within
permissible range.
iii. All temperature indicators shall be operational. (if applicable)
iv. To ensure/verify earthing transformer guard relays contacts making or not.
$
! "#
$ $
7.0
Neutral Earthing Resistor (NER) Testing
a. All general information as required in Appendix A
7.1
Test Form
Requirement
b. At least the following general information of the NER shall be listed.
i.
ii.
iii.
iv.
7.2
Testing
Required
Make
Type
Serial Number
Rated Resistance
a. All testing required/recommended by the manufacturer of the NER and its
accessories shall be conducted and recorded clearly in the test form.
c.
Physical check/inspection to be carried out to check for any :
i.
ii.
Check for any corrosion, damage or defect and galvanizing test.
Control cubicle box shall be airtight and sealed for moisture & vermin
proof.
iii. To confirm no foreign objects (e.g. bar) within the NER.
d. Electrical test to be carried out:
No
1
2
3
Test
Details
NER 33 kV & 11 kV
Using a 5 kV insulation tester
Insulation
resistance
Resistance To be conducted using 5kV
of the NER insulation tester with earth
resistor
connected and disconnected.
NER
Testing on Individual Earthing
Grounding Rods
Resistance
Testing after connected to
earth grid
Limit
Measured value >
500 MΩ
The value shall
conform to the
manufacturer’s
specified value
(± 5%)
Ohmic value shall
preferable not
exceed 10Ω
The ohmic value
shall not exceed
1Ω
$
! "#
$ $
4
NER Blade Measurement of the contact
Switches
resistance to be conducted
between the contacts and
between the arms
• Based on
factory routine
test result/
O&M
• Within
manufacturer’s
recommended
/ tolerance
value as
prescribed in
Routine test /
FAT
• Shall be
consistent for
all blades.
$$
! "#
$ $
8.0
Disconnector Testing
8.1
Test Form
Requirement
a. All general information as required in Appendix A.
b. At least the following general information of the disconnector line shall be
listed.
v.
vi.
vii.
viii.
Rated voltage
Rated current
Operating mechanism
Short circuit rating
a. All general information as required in Appendix A.
8.2
Testing
Required
b. Physical check/inspection to be carried out:
i.
ii.
iii.
iv.
v.
Tightness of connections using correct torque
Insulator bushings checks for cracks and chip off
Earthing connection
Wire and cable connections
Cable entrance to control cubicle shall be from bottom, sealed and water
proof
vi. Heaters and lamps in working order
vii. Ensure recommended thermostat temperature setting label is available
inside the control cubicle
viii. Check for locking facilities (padlock) for both open and close position.
ix. Check linkages and gears lubricated
c.
Mechanical test/check:
i. Alignment checks for the operating blades (manual and motor mode)
No
1
Test
Manual (hand
crank)
operation of
isolator
Details
Manual closing and
opening to confirm contact
pressures, contact
resistance, simultaneous
operation of all phase
operation and ease of
operation
Limit
$%
! "#
$ $
a. Electrical tests:
8.2
Testing
Required
(Cont1)
No
1
Test
Details
Contact
Minimum 100 A DC
resistance for all applied across full
phases
current carrying path
Limit
• Based on factory
routine test result/
O&M
• Within
manufacturer’s
recommended /
tolerance value as
prescribed in
Routine test / FAT
• Shall be
consistent for all
phases.
2
Auxiliary contact • After completion of
alignment &
this test, to mark
timing test
permanently with a
straight line both the
isolator open and
close position.
• Timing of Isolator
open close
To meet factory
tolerances.
b. Operation, indication and interlock test:
i.
ii.
iii.
iv.
v.
vi.
vii.
Inspections on the wiring, position indicators, auxiliary switches,
terminal blocks and components e.g. Labelling, tightness, colour
coding for phases.
Manual operation of isolator shall be conducted e.g. manual closing
and opening
Operational Tests shall be carried out on the operating mechanism
including motor drive unit.
All recommended values and tested values to be recorded e.g.
Duration and switches/protection setting.
Control and operation tests to be carried out e.g. Control, protection,
alarm and indications circuit.
All indications related to the equipment to be tested and proven
working.
Checks and operation shall be made on the Interlocks and safety
features e.g. electrical and mechanical interlocks and safety valves.
$
! "#
$ $
9.0
Current Transformer Testing
9.0
Current
Transformer
Test Form
a. Test Form requirements as per Appendix A.
b. At least the following details of the CT shall be listed.
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
Rated voltage
Rated nominal primary current
Rated maximum primary current
Rated thermal short time current
Short circuit rating
Insulation Power Factor (IPF) value (factory measured)
Serial number for all phases.
Manufacturer details, e.g. Make, type, and model.
Date of manufacturer.
c. The following details of the CT also shall be recorded:
CT intended function – e.g. Distance Protection, Metering
Ratio - To record all ratios and underline the ratio to be used.
Class – e.g. Class 5P20, Class 0.2 etc.
Burden (VA) - Burden of the CT
Vk - Knee point voltage
Im - Magnetizing current
Make - Name of the CT manufacturer
CT type - CT type or model as provided by the manufacturer
Serial No. - Serial no. of the CT unit/phase under test.
Phase - CT phase under test – e.g. R, Y, B, N.
Rated Voltage - The highest operating primary voltage
d. All tests results recorded on the test form shall be crosschecked with the
manufacturer’s factory data.
9.1
Inspection &
Check
Required
Note: This section shall be read together with Section 9 of Appendix N1 of this
chapter.
The following inspections and checks shall be carried out on the CT before any
test:
Confirm CT details are as per the design and specification requirement.
Check nameplate contents are complete.
Check nameplate installed on equipment.
Check nameplate installed on structure.
Physical check on the CT for any damage or defect.
Check that bellow cushion has been removed.
Confirm the primary positioning of the CT – P1 and P2 are according to the
schematic drawing.
Check that the CT terminal box is clean and the seal is in good condition and
confirm the terminal labelling is as per schematic drawing
$&
! "#
$ $
Inspection at the Marshalling Kiosk:
Check that the ratio selection (for a multi-ratio CT) is made at the
Marshalling Kiosk.
Confirm that the star point of the CT is derived at the MK.
Confirm the neutral grounding of the CT secondary.
Check for appropriate shorting link
All the above inspections and checks shall be recorded.
9.2
Testing
Conditions &
Restrictions
a. The following conditions shall be adhered when performing SAT on CT:i.
All access to CT secondary wiring during testing shall be made at the
marshalling kiosk (MK).
ii.
For CTs in which the primary terminals are not accessible at all i.e.
transformer bushing mounted CTs, the polarity and the ratio shall be
confirmed during the on-load commissioning test.
b. The following conditions shall be adhered when performing SAT on CT:-
9.3
Testing
Required
i.
All access to CT secondary wiring during testing shall be made at the
marshalling kiosk (MK).
ii.
For CTs in which the primary terminals are not accessible at all i.e.
transformer bushing mounted CTs, the polarity and the ratio shall be
confirmed during the on-load commissioning test.
All testing required/recommended by the manufacturer of the CT and its
accessories shall be conducted and recorded clearly in the test form.
a. Physical check/inspection to be carried out:
i.
ii.
iii.
iv.
v.
vi.
vii.
b.
Inspect physical conditions: no damage, no missing hardware and correct
vertical and horizontal alignment
Correct oil level and consistence between all phases
Check for oil leak (if applicable);
Verify correct mounting of the CT, earth connections and electrodes
Check cable entrance for tidiness, protection from sharp metallic edges,
no injury in insulation and vermin proof.
Visual check of primary and secondary circuits against approved
drawings.
Using circuit diagram, check that P1 and P2 primary terminals are
correctly connected
Electrical tests to be carried out:
i.
DC Insulation Resistance test
• Between primary and earth (5 kV)
• Between secondary and earth (1 kV)
• Between primary and secondary (5 kV)
ii.
Polarity test
• All tappings shall be flick tested
• For CT polarity tests using the flicking method, analog voltmeters
shall be used.
$"
! "#
$ $
iii.
Measurements of the CT resistances
• shall be taken at the CT terminal.
• For CTs used in high impedance protection schemes, loop resistance
measurements shall be made on all current transformers.
• Lead resistance and all measurements shall be recorded on the lead
resistance diagram.
iv.
Magnetisation test
• A minimum of 10 readings shall be obtained to plot the magnetization
curve.
• The curve shall be plotted immediately and compared with the factory
test report and the comparison to be recorded.
• The knee point voltage from the plotted magnetization curve shall be
identified and compared with the rated value. This comparison shall
be recorded.
• Magnetization curves for all CT phases meant for a specific
protection/function shall be plotted on the one graph only. This is to
confirm that the CT characteristics match. This confirmation shall be
recorded.
• For CTs where the knee-point is above 2kV, the saturation point from
factory test report shall be acceptable.
• Effect of remenance flux shall be minimised during the test.
v.
Ratio Test
• This test shall only be carried out after the completion of the above
tests.
• For multi-ratio CTs, all ratios shall be checked. The ratio that is
intended for use shall be tested last.
• The rated burden of the CT shall be connected during the ratio
check.
• The primary current value shall be equivalent to the rated value or
600A whichever is lower.
• Ratio test may be repeated after performing demagnetization test
incase ratio test failed.
vi.
Power Factor
No
1
Test
Details
Power Factor To check uniformity of
results due to transportation
and storage in relation to
factory results. The values
shall be referred at the rated
frequency.
Test voltage is to be 10kV at
power frequency.
Record the correction factor
to 20°C and record the
temperatures. For all
phases, record the value of
IPF corrected to 200 C.
vii.
Limit
1) <0.5% at
20°C
2) Power factor
for all three
phases
<100%
difference
between
phases.
Test done by TNB
with presence of
Contractor/OEM
Capacitance measurement
•
Measurement of capacitance shall be as a finger print test as a
reference value for end of warranty test.
$'
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$ $
Test done by TNB with the presence of the contractor.
viii.
10.0
Additional test for interposing Current Transformer (ICT)
• Vector group test - Only for ICT used in Differential Protection
scheme.
• Impedance test - Only for ICT used in Differential Protection
scheme.
i. Measurement of Positive Sequence Impedance
ii. Measurement of Zero Sequence Impedance
Voltage Transformer Testing (Capacitive / Inductive)
a. Test Form requirements as per Appendix A.
10.1
Capacitive /
Inductive
Voltage
Transformer
Test Form
b. The following details of the VT shall be recorded.
VT intended function – e.g. Distance Protection, Metering
Ratio - To record all ratios and underline the ratio to be used.
Class
Burden (VA) - Burden of the VT
Make - Name of the VT manufacturer
VT type - VT type or model as provided by the manufacturer
Serial No. - Serial No. of the VT unit/phase under test.
Phase - VT phase under test – R, Y, B.
Rated Voltage - The highest operating primary voltage
At least the following details of the VT shall be listed.
i.
ii.
iii.
iv.
v.
vi.
Rated voltage
Serial Number
Core number, ratio, Class and Burden
Short Circuit rating
Capacitive value and associated tolerance
Data of manufacturer
All test results recorded on the test form shall be crosschecked with the
manufacturer’s factory data.
At least the following details of the Intermediate Voltage Transformer (IVT)
shall be mentioned.
Winding & Ratio
Serial No.
Nominal Intermediate Voltage
10.2
Inspection &
Check
The following inspections and checks shall be carried out on the VT before any
test:
$(
! "#
$ $
Required
a. Confirm VT details are as per the design and specification requirement.
Check nameplate contents are complete.
b. Physical check on the VT for any damage or defect.
c.
Check that bellow cushion has been removed.
d. Confirm the primary positioning of the VT – e.g. a and n are according to the
schematic drawing.
e. Check that the VT terminal box is clean and the seal is in good condition and
confirm the terminal labelling is as per schematic drawing.
f.
Inspection at the Marshalling Kiosk:
Check that the ratio selection (for a multi-ratio VT) is made at the
Marshalling Kiosk.
Confirm that the star point of the VT is derived at the MK.
Confirm that the neutral grounding of the VT secondary.
f.
Check Oil Level (if any) is within the permissible range
g. All the above inspections and checks shall be recorded.
10.3
Testing
Required
a. All on-site tests as recommended in the VT manual.
b.
All testing required/recommended by the manufacturer of the VT and its
accessories shall be conducted and recorded clearly in the test form.
c.
Physical check/inspection to be carried out.
i. Check correct oil level (if applicable);
ii. Verify satisfactory mounting of the VT, earth connections and electrodes
iii. Inspect physical conditions: no damage, no missing hardware and correct
vertical and horizontal alignment
iv. Check cable entrance for tidiness, protection from sharp metallic edges,
no injury in insulation and vermin proof.
v. Visual check of primary and secondary circuits.
d.
Electrical tests to be carried out for capacitive VT:
No
Test
1 Capacitance
measurement
Details
Total Capacitive
measurement
Limit
Capacitance ±5%
variance from
nameplate/factory
measurement.
Test done by TNB
with presence of
Contractor/OEM
$)
! "#
$ $
2
Insulation
resistance test
The test shall be
conducted between:
No disruptive
discharge
Consistent for all
phases
>10MΩ
**Polarization Index to
Secondary to earth (1kV) be performed if value
<10MΩ
Primary to earth (5kV)
Primary to
Secondary(5kV)
3
Ratio test
at least 1% of the
primary rated voltage
shall be injected and all
windings shall be tested
4.
Power Factor
To check uniformity of
results due to
transportation and
storage in relation to
factory results. The
values shall be referred
at the rated frequency.
Test voltage is to be
10kV at power
frequency.
Record the correction
factor to 20°C and record
the temperatures. For all
phases, record the value
of IPF corrected to 200 C.
e.
Within manufacturer’s
recommended /
tolerance value as
prescribed in Routine
test / FAT
1) <1% at 20°C
2) Power factor for
all three phases
<100% difference
between phases.
*Test to be done
without isolating
EMU from
capacitive divider.
Test done by TNB
with presence of
Contractor/OEM
Electrical tests to be carried out for inductive VT:
No
1
2
3
4
Test
Power Factor
(C1)
Capacitance (C1)
Details
Measurement of power
factor of the IVT.
Total Capacitive
measurement
Insulation
resistance test
The test shall be
conducted between:
Ratio test
Limit
<0.5% at 20°C
Not to exceed ±5%
variance from FAT
test measurement.
No disruptive
discharge
• Primary to earth
(5kV)
Consistent for all
phases
• Secondary to
earth (1kV)
• Primary to
Secondary(5kV)
>10MΩ
**Polarisation Index
to be performed if
value <10MΩ
at least 1% of the
primary rated voltage
shall be injected and all
windings shall be tested
Within
manufacturer’s
recommended /
tolerance value as
prescribed in
Routine test / FAT
%
! "#
$ $
10.4
Additional
Check
Check name plate installed on equipment.
Check name plate installed on structure.
Check both name plates are complete and in order.
Confirm single pole MCB (one MCB for each phase) is used at MK for all VT
circuits. Confirm alarm is provided if the MCB is tripped.
Record rating of fuses/MCB at VT boxes. Records rating of single pole MCB
at MK. Ensure the rating of MCB’s and fuses are discriminated accordingly.
Confirm grounding of VT secondary is done at the VT.
Confirm grounding of Intermediate VT is according to manufacturer
recommendation except for CVT with line coupling unit for PLC equipment for
all phases.
Check ground switch is closed when PLC equipment not in use for all phases
(if available)
Check voltage tap ground switch is kept open for all phases.
10.5
Special
Tests for
Inductive
Voltage
Transformer
11.0
For Inductive VT testing, where applicable, the above requirement shall
apply.
Induced Voltage Test at rated secondary voltage. Necessary precautions
shall be taken during this test.
Capacitor Bank Testing
11.1
Test Form
Requirement
a. All general information as required in Appendix A.
b. At least the following details of the Capacitor Bank shall be listed.
i.
ii.
iii.
iv.
v.
11.2
Testing
Required
Capacitance value
Date of manufacture
Manufacturer
Type
Serial number
a. All testing required/recommended by the manufacturer of the Capacitor Bank and
its accessories shall be conducted and recorded clearly in the test form.
b. Physical check/inspection to be carried out:
i.
ii.
iii.
iv.
v.
vi.
vii.
All live parts (terminals, cap, etc) shall be shrouded
Physical check on the equipment for any corrosion, damage or defect
Check for correct connection diagram
Check for correct labeling
Earth connections
Tightness of connections using correct torque
To check alignment of connections
%
! "#
$ $
viii. Insulators undamaged and clean
ix. Safety clearances
x. Check for missing components
c.
Electrical tests to be carried out after the installation the capacitor shall be
tested by the:
No
1
Test
Capacitance
Measurement
2
Internal
Discharge
Resistor
Value
Point of wave
switching
3
Details
Measurement shall be carried
out
for
the
following
arrangement:
• Each Can
• Each Stack
• Each Phase
Limit
Within tolerance
declared
by
manufacturer
> 20% of factory
test value
This test shall be carried out by
current and voltage injection
and
CB
operation.
The
performance of CB opening and
closing shall be monitored and
compared with waveform using
disturbance recorder. TNB will
assist this test by providing the
disturbance recorder and the
printout. Analysis of the printout
shall form part of the test report.
Within tolerance
declared
by
manufacturer.
4.
Capacitor
can terminalto-terminal
insulation
resistance
test.
1. All
values
shall exceed
1G .
2. Values shall
be consistent
for all cans.
5.
Capacitor
can terminalto-case
insulation
resistance
test.
3. All
values
shall exceed
1G .
4. Values shall
be consistent
for all cans.
%$
! "#
$ $
12.0
Surge Arrestor Testing
12.1
Test Form
Requirement
a. All general information as required in Appendix A.
12.2
Testing
Required
a. All testing required/recommended by the manufacturer of the reactor and its
accessories shall be conducted and recorded clearly in the test form.
b. At least the following details of the Surge Arrester shall be listed
i. Rated voltage (kV)
ii. Continuous volt (kV)
iii. Nominal discharge current (kA)
iv. Short circuit rating
v. Leakage current
vi. Serial number of each phase
vii. Type, e.g. zinc oxide, gapless, gap, etc.
viii. Date of manufacture
ix. Class
b. Physical check/inspection to be carried out:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
Verify correct mounting of the SA, counter, earth connections and
electrodes.
Verify that the pressure-relief discharge nozzles are not directed as to harm
neighboring equipment when they operate.
Verify that the earthing connections are as straight and short as possible
so as not to reduce the SA protective level & to avoid high frequency
phenomenon during surges.
Verify the insulated connections from SA earthing terminal to surge counter
and leakage current meter.
Verify that the edge-to-edge distance between grading rings conforms to the
required phase-phase distance.
Inspect physical conditions: no damage, no missing hardware and correct
vertical and horizontal alignment
Verify that the SA base is insulated from the equipment structure.
The counter display shall be visible, free from crack and moisture
condensation
%%
! "#
$ $
12.2
Testing
Required
(Cont1)
c.
No
1
2
Electrical tests to be carried out:
Test
DC Insulation
Resistance Test
Watt Loss
Details
To indicate condition of
arrester
housing
and
elements,
this
can
be
compared to other similar units
unless
moisture,
foreign
deposits
or
other
contamination are present.
The test shall be conducted
between primary terminals to
earth of all phases using a 5kV
insulation tester
Measurement of Watt Loss
Limit
>100 M
<0.1W (TNB suggested
limit)
Test done by TNB with
presence of
Contractor/OEM
%
! "#
$ $
13.0 Sealing End Testing
13.1
Test Form
Requirement
c.
All general information as required in Appendix A.
d. At least the following details of the Sealing End shall be listed
i.
ii.
iii.
Rated voltage (kV)
Serial number of each phase
Date of manufacture
______________________________________________________________
13.2
Test Required
a. All testing required/recommended by the manufacturer shall be conducted and
recorded clearly in the test form.
b. Physical check/inspection to be carried out:
i.
ii.
iii.
iv.
Physical check on the equipment for any corrosion, damage or defect
Labeling
Earthing connections
Missing components
a. Electrical tests for dry type reactor to be carried out:
No
1
Test
Insulation
Resistance
Details
The test shall be performed
using a 500 V insulation
tester except for HV – E, 5
kV insulation tester shall be
used. The following
measurement shall be
recorded: 1. Between Primary
and Earth
Limit
All values shall
exceed 200 MΩ
%&
! "#
$ $
14.0
Reactor (Oil Immersed Type) Testing
14.1
Test Form
Requirement
a. All general information as required in Appendix A.
b. At least the following details of the Reactor shall be listed
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
Rated voltage
Rated current
Short circuit rating
Operating mechanism
Capacity
Manufacturer
Manufactured Date
Impedance
a. All testing required/recommended by the manufacturer of the Surge Arrestor
and its accessories shall be conducted and recorded clearly in the test form.
14.2
Testing
Required
b. Physical check/inspection to be carried out:
i.
ii.
iii.
iv.
Check on the equipment for any corrosion, damage or defect.
Impact Recorder Reading.
Inert gas pressure.
Co-coordinating gaps (alignment and gap measurement) where
applicable.
v. Labelling
vi. Earthing connections
vii. Explosion vent / pressure relief device
viii. Breathers
ix. Valves in operational positions
x. Tightness of fastenings
xi. Insulators/bushings undamaged and clean
xii. No oil leaks.
xiii. Correct oil levels in main tank conservator
xiv. Safety clearances.
xv. Missing components
xvi. Ensure all terminal blocks, oil level gauges and other accessories are fully
sealed/moisture and vermin proof
%"
! "#
$ $
c.
14.2
Testing
Required
(Cont1)
Electrical tests to be carried out:
No
Test
1
Insulation
Resistance
2
Winding
Resistance (DC)
3
Winding Power
Factor
Bushing Power
Factor
(If Applicable)
4
Details
Limit
The test shall be
IR at 1 minute > 1G
performed using 5 kV
insulation tester. The
following measurement
shall be recorded: between Primary and
Earth.
1. Within
+5%
between
phases
after correction to
75°C
2. Consistence
between phases
Test done by TNB
with
presence
of
Contractor/OEM
Measurement of Power < 0.5% at 20°C
Factor of all windings
Measurement of Power For C1:
Factor of Bushing
1. < 0.7%.
2. Power factor for all
three phases <100%
difference between
phases.
∗ For any bushing
where the power
factor difference
exceeds 100%, to
be replaced.
For C2:
1. C2 bushing power
factor < 5%
Capacitance
change
+5% from FAT result
(Test done by TNB in
the presence of the
contractor.)
5
Oil Power Factor
Measurement of Power < 0.1% at 20°C
Factor of oil
Test done by TNB
with
presence
of
Contractor/OEM
%'
! "#
$ $
d. Following are insulating oil tests:
No
1
2
3
Property
Absolute Water
Content in ppm
(Not temperature
corrected)
Neutralization
Value (mg KOH/g)
Interfacial
Tension (mN/m)
4
Color
5
Electric strength,
kV (breakdown
voltage)
6
Dielectric
Dissipation Factor
at 90°C
Limit
Highest Voltage for
Equipment
(≤ 72.5 kV)
Test Standard
< 10
IEC 422
Max 0.03
IEC 422
Min 40
IEC 422
Max 2.0
IEC 422
> 60
IEC 422
Max 0.015
e. Functional test:
14.2
Testing
Required
(Cont2)
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
f.
All testing required/recommended by the manufacturer of the reactor.
Calibration of all oil and winding temperature indicators.
Cooling fan and/or pump operation check- if provided
Reactor guard check – all alarm, indication, flags, fascia and relay
operation at reactor, RCC, relay panel and control panel to recorded
clearly. Simulation method for each signal shall also be mentioned.
Check name plate provided on equipment
Check Oil Level (if any) is within permissible range.
Audible sound level test.
Vibration Test
Mechanical tests:
No
1
Test
Oil leak test
Condition
The reactor shall be able to withstand a pressure
of 30 kPa / 0.3 Bar from the top of conservator
filled with oil for 24 hours with no oil leakage and
no permanent deformation on the structure.
%(
! "#
$ $
15.0
Reactor (Dry Type) Testing
15.1
Test Form
Requirement
a. All general information as required in Appendix A.
b. At least the following details of the Reactor shall be listed
ix.
x.
xi.
xii.
xiii.
xiv.
xv.
xvi.
15.2
Test Required
Rated voltage
Rated current
Short circuit rating
Operating mechanism
Capacity
Manufacturer
Manufactured Date
Impedance
a. All testing required/recommended by the manufacturer of the Reactor and its
accessories shall be conducted and recorded clearly in the test form.
b. Physical check/inspection to be carried out:
v.
vi.
vii.
viii.
c.
Physical check on the equipment for any corrosion, damage or defect
Labeling
Earthing connections
Missing components
Electrical tests for dry type reactor to be carried out:
No
1
Test
Insulation
Resistance
2
Impedance
@ rated
voltage
Insulation
Power
Factor
3
Details
The test shall be
performed using a 500
V insulation tester
except for HV – E, 5 kV
insulation tester shall
be used. The following
measurement shall be
recorded: 2. Between
Primary and
Earth
Limit
All values
shall exceed
200 MΩ
Standards
TNB
standard
Limits within
±5%
TNB
standard
TNB
standard
Test done
by TNB with
presence of
Contractor/
OEM.
%)
! "#
$ $
16.0
Switchyard Installations Testing
16.1
Test Form
Requirement
a.
All general information as required in Appendix A.
b. At least the following details of the switchyard installations shall be listed.
i.
ii.
iii.
iv.
v.
vi.
vii.
16.2
Testing
Required
Busbar capacity
Down dropper sizes
Connectors make
Earthing system
Gantry
Earth mast
Switchyard lighting
a. All testing required/recommended by the manufacturer of the switchyard
installations and its accessories shall be conducted and recorded clearly in
the test form.
b. Physical check/inspection:
i.
ii.
Phasing connection check
Check for proper feeder and switching device labelling, e.g. use of
aluminum, embossed and proper size and riveted.
iii. Check phase indication color
iv. Check bolts tightness (correct torque)
v.
Surface contact for earthing conductor
vi. Tinning of copper interfaces with other metals
vii. Visual inspection of busbar alignment
viii. Check on galvanizing, rust, etc.
ix. Earthing connection as per engineering approval
x.
Visual inspection of earthing connections at the steel structure for tidy
workmanship
xi. Check all fitting tightness for insulators and bushing (correct torque)
xii. Check all welded points where applicable.
xiii. Ensure all bolts and nuts are tied with washers and spring washers in
correct position.
xiv. Ensure exposed earth tape painted completely.
xv. Check marshalling kiosks for sealed door, proper ventilation, functioning
heater and lightings.
xvi. Electrical, safety, statutory and ground clearances to conform to
specification.
xvii. Check of no broken strands, no rubbing between earth mast conductors,
and correct fittings of earth masts.
xviii. All connections shall be treated with contact grease/paste and free from
water collection and rust. Clamp shall be cleaned by emery paper /
metallic wire brush.
xix. To check bi-metal link application for aluminum-copper.
xx. To ensure lighting arrester to be removed at gantry with SA
xxi. To check Stone chipping thickness shall be more than 150mm
xxii. Flexible busbar and connection shall be checked to ensure that the
correct tensions, sags and clearances will be maintained in different
environmental conditions and loads without stress to other equipment.
xxiii. Rigid busbar and connections shall be checked to ensure that there will
be no overloading of the supporting insulators under load conditions and
under different environmental conditions
xxiv. Busbar clamp type installed as per TNB approval – e.g. Expansion,
! "#
$ $
Sliding, fixed and contraction is accommodated by flexible connections.
16.2
Testing
Required
(Cont1)
c.
Electrical/mechanical test to be carried out:
i. Torque measurement shall be carried out on all flexible conductor,
connections
ii. Contact resistance test shall be carried out on all flexible busbar,
connections and joints, which are made at site. This may be carried out as
a complete circuit test of a bay and the reading between phases shall be
uniform.
d. Earthing check/test:
i. Test shall be made on the effectiveness of the bonding and earthing
connections.
ii. Checks shall be also made on precautions taken to avoid corrosion
attack on the earthing system.
iii. The earth resistance shall be measured and recorded as follows: a) Earth grid after completion and backfilling of the trenches. Value
shall be less than 1Ω.
b) Individual earth rods resistance measured shall preferably be less
than 10Ω for SA, NER and Transformer HV Neutral.
! "#
$ $
17.0
11kV and 33kV Switchgear Testing
17.1
Test Form
Requirement
a. All general information as required in Appendix A.
b. At least the following details of the metalclad switchgear shall be listed.
i.
ii.
iii.
iv.
v.
vi.
vii.
Rated voltage
Rated current
Operating mechanism
Serial number
Model
Manufacturer
Date of manufacture
a. All testing required/recommended by the manufacturer of the metalclad
switchgear and its accessories shall be conducted and recorded clearly in the
test form.
17.2
Testing
Required
b. Physical check/inspection:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
xi.
xii.
Proper labeling on panel front, rear and CB truck.
Earthing switch connected to earth grid.
Busbar shutter operation and VCB truck alignment and racking in/out
Cable entry e.g. Proper clamping and sealed
Dust and Vermin proof i.e. all holes shall be covered externally and
internally, including the earth switch-operating rod (rubber lining for
door and boot for the earth-operating rod to be installed.
Tightness of connections using correct torque
Earthing connection
Wire and cable connections
Cable entrance to control cubicle shall be from bottom, sealed and
water proof
Heaters and lamps in working order
Ensure recommended thermostat temperature setting label is
available inside the control cubicle
Locking facilities
$
! "#
$ $
c.
17.2
Testing
Required
(Cont1)
Electrical test to be carried out:
No
1
Test
Power
frequency
withstand test
(AC pressure
test)
Details
Test voltage equals 70
kV for 33kV S/G, 50 kV
for 22kV S/G and 28 kV
for 11 kV S/G for 1
minute.
Test to be performed on
busbar inclusive of
circuit breaker in closed
and open position
2
CB Timing test
3
Insulation
resistance of
the busbar &
individual CB
before and after
power freq. test
Vacuum check
on vacuum
bottle.
Contact
resistance
measurement
on breaker.
Complete circuit
loop resistance
measurement.
4
5.
6.
This test shall be
conducted on each
phase with the 2
remaining phases
earthed.
To check for closing &
tripping time, closing
and tripping coil current.
check synchronism of
main contacts for all
phases.
•
Close and trip
timing
•
C-O timing.
Testing conducted by
using a 5 kV insulation
tester
Limit
No flashover shall occur.
Stable leakage current
readings.
This test shall be
conducted under stage 4
(after completion of all
tests).
As manufacturer’s
recommended tolerance.
More than 1 G
No discharge.
Consistent value
As manufacturer’s
recommended tolerance
Minimum of 100amps
DC shall be applied.
To conform to the routine
tests value
Minimum of 100amps
DC shall be applied.
Measured value for all
phases shall be
consistent.
This test shall be
performed for complete
circuit with isolators and
CB for each phase.
%
! "#
$ $
d. Operation, indication and interlock test:
17.2
Testing
Required
(Cont2)
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
Inspections on the wiring, position indicators, auxiliary switches, terminal
blocks and components e.g. labelling, tightness, color coding.
Insulation test of control wiring and auxiliary devices.
Manual operation of switchgear shall be conducted e.g. slow closing,
manual spring charging, and manual tripping.
Operational Tests shall be carried out on the spring operating system.
All recommended values and tested values to be recorded e.g. Duration,
switches/protection setting and counter readings
Control and operation tests to be carried out e.g. Control, protection,
alarm and indications circuit
All indications related to the equipment to be tested and proven working
Checks and operation shall be made on the Interlocks and safety
features e.g. Electrical and mechanical interlocks and safety valves
e. Special requirements for 33kV & 11KV SF6 insulated switchgears.
i.
All testing required/recommended by the manufacturer of the 33kV &
11kV SF6 insulated switchgear and its accessories shall be conducted
and recorded clearly in the test form.
ii. To check for SF6 gas leak.
iii. Insulating medium test (SF6) as follows:
No
1
! "#
2
Test
Moisture
Content
SF6 purity test
3
S02 Content
$ $
Details
SF6 dew point test
Limit
< -23o C
To check composition of > 97%
SF6 gas at every
compartment
To check S02 content
< 12ppmv
inside each
compartment
18.0
Standby Diesel Engine Driven Generator
a. All general information as required in Appendix A.
18.1
Test Form
Requirement
b. At least the following detail of the generator shall be listed
i.
Make
ii.
Type
iii.
Serial Number
iv.
Rated Voltage
v.
Date of manufacture
vi.
Continuous output kW
vii.
Continues output KVA
a. All testing required/recommended by the manufacturer of the Standby
Generator Standby Diesel Engine Driven Generator and its accessories
shall be conducted and recorded clearly in the test form.
18.2
Test Required
b. Physical check/inspection to be carried out:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
Visual inspection on engine, alternator, radiator, and various
systems of the generating set
Visual inspection on Control Cubicle
Visual inspection on welding surfaces and primer coating for
Underground/ Daily Services Fuel Tank
Physical check on the equipment for any corrosion, damage or
defect
Proper labeling
Effective and adequate earth bonding have been provided for the
engine and alternator.
Missing components
Tightness of connections using correct torque
Wire and cable connections
Locking facilities
c. Electrical/ Mechanical tests for Standby Generator Standby Diesel
Engine Driven Generator to be carried out shall include but not limited to:
1. Tests on the wiring installation in accordance with Section E of the
IEE Regulations including tests on the earthing system.
2. Earth electrode resistance tests to the general mass of earth
3. Check of insulation resistance for all electrical machines
4. Check for correct operation of fuel oil system
5. Check for correct lubricant and coolant levels.
6. Battery charger output test
7. Check for correct operation of the following: i) Governor and engine speed adjustment.
ii) All safety devices.
iii) All manual controls.
iv) All alarms, indicators, instruments, meters and gauges.
v) Voltage regulation.
&
! "#
$ $
8. Load Test - Up to 8 hours reliability trial run shall be carried out by
the contractor. This trial run may have to be carried out at night,
possibly after midnight. The contractor shall provide a resistive load
of sufficient capacity for this test. All necessary fuel required for such
test shall be furnished by the contractor at his own expense.
9. Load transfer test
10. Meter readings, gauge readings, satisfactory operation of all devices,
manual controls, etc., shall be noted and included on the test
certificates.
11. Acoustic noise level measurement shall not exceed 70dB at 1 meter
from enclosure wall
"
! "#
$ $
SAT Appendix K: SAT for Lines and Cable
1.0
2.0
3.0
Purpose ........................................................................................................................1
Transmission Line Testing ............................................................................................1
Power Cable Testing ....................................................................................................6
To provide SAT requirements when carrying out Lines and cable test
1.0
Purpose
2.0
Transmission Line Testing
a. All general information as required in Appendix A.
2.1
Test Form
Requirement
b. At least the following details of the switchgear shall be mentioned in test sheet:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
Name of line
Lines rating, capacity, voltage
Conductor Type
Earth wire / OPGW
Total number of towers
Type of towers
Route length
All electrical, safety, ground and statutory clearances to be declared.
GPS coordinate
c. At least the following details of the transmission line shall be listed for each tower
inspected
i. Tower Type (inc details of Body & Leg Extension)
ii. Tower Number
iii. Date of Inspection
2.2
Testing
Required before OHL
commissioning
a. All testing required/recommended by TNB and the manufacturer of the
transmission lines and its accessories, shall be conducted and recorded clearly
in the test form
b. Physical check/inspection:
! "#
i)
Rentice
a) Measurement of width of rentice
b) Undergrowth removal (to be maintained within 300mm)
c) Danger trees to be cleared
d) Debris leftover to be cleared
e) Centerpath within the rentice
f) Electrical, safety, statutory and ground clearances to conform to specification
g) Activities and permanent structures
h) Any crossing (River, road, utilities, railways)
ii)
Conductor/Earth Conductor/OPGW
a) Damage/broken strands
b) Number of mid span joint
c) Earth wire bonding / jumper
d) Condition of armour rod (if applicable)
$ $
2.2
Testing
Required before OHL
commissioning
(Cont 1)
e) Phase Jumper
iii) Foundation
a) Soil erosion
b) Concrete surface for cracks
c) Drainage
d) Turfing
e) Foundation frustrum
iv) Tower Earthing System
a) Design of Tower Earthing (as per drawing)
b) Type of counterpoise
c) Type of rod
d) Connection of counterpoise and rod (must be by EXOTHERMIC welding
only, no U-Bolts are allowed)
e) Paint
f) Soil Resistivity measurement
g) TFR measurement
v) Lattice structures
a) Tightness of bolts, nuts and washers and minimum of 3 bolt threads leftover.
(To be checked using torque wrench)
b) Step bolts above ACD
c) Galvanising (more than 86 micron) and paint
d) Vandal proof bolts and nut
e) Check for Missing member
f) Painting of chimney cap
g) Phase plate
h) Airborne plate
i) Anti-climbing device (ACD)
j) Danger plate
k) Rest platform
l) Tower painting if applicable
vi) Insulators (cap & pin)
a) Check for Zinc sleeve for all towers (porcelain/glass) All insulators supplied
are with zinc sleeve
b) Insulator details per string (i.e. quantity, type of insulator etc.)
c) Physical condition (crack, cleanliness, broken, chip)
d) Uniform and even surface of cement base (at pin area) prior to installation
vii) Insulators (composite)
a) Insulator details per string (i.e. quantity, type of insulator etc.)
b) Physical condition of rubber sheds (crack, cleanliness, broken, chip)
c) End fitting seal (rubber to the metal fitting interface area at both end)
viii) Tower Lightning arrester (TLA)
a) Tower number (where it is supposedly to be installed).
$
! "#
$ $
2.2
Testing
Required before OHL
commissioning
(Cont 2)
b)
c)
d)
e)
f)
Installation arrangement -phases on tower (as per instructed arrangement)
Gap distance (as per OEM’s recommendation & drawing)
Tightness of bolts, nuts and washers
Downlead conductor to connect to tower body (for wooden/composite
crossarms)
Fault indicator, if any (proper installation)
ix) Fittings
a) Earthwire
1. Tightness of bolts, nuts and washers
2. Installation of split pin for D-shackles
3. Spiral damper for OPGW
4. Vibration damper for ACSR Skunk
5. Downlead clamp for OPGW earthwires
b) Conductor
1. Number of spacers or spacer damper for phase conductors
2. Quantity and type of vibration dampers for both phase conductor and
earth wire
3. Tightness of bolts and nuts for jumper tube
4. Spacer damper and damper installation shall be as the approved
placement chart.
c) Insulator
1. Installation of locking device - W clips (R clips stainless steel for 500kV)
2. Tightness of bolts, nuts and washers
3. Vertically of string shall not deviate more than 2 degrees (for single
suspension string)
4. Split Pins
x) Torque check at all electrical connections/fittings e.g. jumper, dropper and
landing to be recorded.
xi) OPGW joint box to be located at the middle cross arm and 3 meter above the
ground on substation gantry (subjected to alteration) with the facility to be
lowered to ground level and equipped with sufficient down lead clamp.
xii) ADSS for sag and proper fitting to tower body
xiii) Solar panel and battery, control panel, light, cable and aircraft warning spheres.
c. Electrical check / test
i) Test for Optical Fibre Cables/OPGW
No
Test
Details
1
Total
A laser source and power
Attenuation
meter shall be used for
Test
these attenuation
measurements. End to end
test to check the continuity
of each fibre. The
measurement shall be done
from both ends and the
average computed. Test
shall be done with two
wavelength, 1310nm and
1550nm.
Limit
The value shall be less than
Calculated Value.
Formula:
Value < Cxd + Sxn + Kxk
C=Fibre Cable Lost (constant)
d=Fibre Cable Length
S=Splice Loss in dB (constant)
n=Number of splices
K=Connector Loss in dB
(constant)
k=Number of Connector
%
! "#
$ $
2.2
Testing
Required before OHL
commissioning
(Cont 3)
C=0.40dB/km at 1310nm
wavelength
0.25dB/km at 1550nm
wavelength
S=0.10dB for both wavelength
K=0.50dB for both wavelength
2
ii)
Splice Loss
Test
An optical time domain
reflectometer (OTDR) shall
be used for these
attenuation measurements.
The measurements shall be
recorded by a printer. The
optical loss measured shall
not exceed the specified
maximum allowable
attenuation for the per unit
loss. Test shall be done
with two wavelength,
1310nm and 1550nm.
The value shall not be more
than 0.10dB.
Measurement of TFR (using high frequency equipment):
a) One measurement on each erected tower before stringing, without earth
connection.
b) One measurement on each erected tower before stringing, complete with
earth connection.
- using Fluke & Chauvin Arnox. Only this two brands of earthing measurement
equipment suitable for the application of Transmission towers are acceptable
and allowed to be used.
-
Limits of 10 ohms for 132kV & 275kV, 5 ohms for 500kV
Limits of 5 ohms for all Monopoles
iii) Line test/check
a) Line Impedance
b) Induced voltage measurement
c) Insulation resistance test
d) Phasing test
e) D.C Resistance test
iv) Measurement to be carried out on conductor/earth/OPGW conductor:
No
1
Test
Conductor
sagging
Details
Sagging measurement of
each conductor at the lowest
point is to be carried out and
properly recorded.
Limit
Shall not depart from the
correct erection sag by more
than -4% and conductors
forming the pairs in each
phase shall not differ from
each other by more than 40
mm
2
Conductor
to connector
resistance
Resistance measurement of
each jumper, dead end clamp
and mid span joint to be
carried out and properly
recorded.
Resistance of any such ittings
shall not exceed 75% of the
resistance of an eqv. length of
conductor,measured adjacent
to the fitting, and the current
carrying capacity shall be at
least 100% of that of the
conductor.
Conductor resistance values:Curlew – 0.0548 /km
! "#
$ $
Zebra – 0.0674 /km
Batang - 0.08914 /km
Wolf – 0.1828 /km
Skunk – 0.4566 /km
TACSRCurlew-0.0434
TACSR Zebra- 0.0534
ACCC Lisbon- 0.0887
ACCC Dublin- 0.0534
/km
/km
/km
/km
ACIR 275kV – 0.0674 /km
ACIR 132kV – 0.0892 /km
For other conductors please
refer to manufacturer’s
declared values.
d. Functional Checks
i)
ii)
iii)
iv)
Air craft warning light system
Bulb
Photocell
Charger
&
! "#
$ $
3.0
Power Cable Testing
a. All general information as required in Appendix A.
3.1
Test Form
Requirement
b. At least the following general information of the power cable shall be listed.
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
xi.
xii.
Cable (insulation) type
Cable length
Route length
Cable Rating ( Voltage, MVA)
Short circuit rating
No of feeders
Conductor size
No of core
Sheath bonding (direct earth or open end)
Date of manufacture
Pressure Tank details ( No of cells, volume, gas constant)
All electrical, safety, ground and statutory clearances to be declared.
a. The following requirement shall apply for all type and voltage level above 11kV
of Power Cable installation e.g. Transformer tail, transformer cable, feeder
cable & interconnector cable, unless stated otherwise.
3.2
Testing
Required
b. All testing required/recommended by the manufacturer of the cable system and
its accessories shall be conducted and recorded clearly in the test form.
c.
Verification of all buried works e.g. sand bedding, cable depth check,
PVC/HDPE pipe class, laying configuration, joint bay layout shall be carried
out span by span.
d. Physical check/test required:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
xi.
xii.
xiii.
xiv.
xv.
xvi.
xvii.
xviii.
xix.
xx.
Check cable route markers
Check cable joint markers.
Check link boxes
Check of cable tagging i.e. jointers’ ID.
Correctly sized earthing bar/leads
Verify the labelling of the phases, circuits and feeder name
Verify the direction indications of leads
Verify the use of sand bedding (span by span check before jointing, by
project supervisor).
Check pressure of oil.
Check for no crack/chip-off at cross bond link boxes.
Check for no rust.
Verify sufficient clearances are met.
Check for all the terminations were done correctly/properly.
Check for sufficient creepage distances for terminations.
No physical damage/scratch marks at the outer jacket.
No oil leak at the cable box.
No cracked/split tape at the termination in the oil filled cable box.
Verify the use of crimped, cast type cable lugs (for 33kV and 11kV
transformer cable tail only).
Verify the use of cable slabs (concrete reinforced).
Bending radius shall not exceed manufacturer’s specified value.
xxi. Check on the trenches (if applicable).
"
! "#
$ $
•
•
•
•
3.2
Testing
Required (Cont
1)
xxii.
xxiii.
xxiv.
xxv.
Smooth, finished concrete
Cable shall not touch the trench corners
Trays won’t collapse
Ensure no multiple circuits laid on top of each other.
Check for Cathodic Protection
Check for cable ducting e.g. PVC, HDPE
Check on Multiple Cable Transit (MCT) if available
Check Cable Bridge (structure, covers, anti-crossing device and
signage).
e. Electrical tests to be carried out:
i.
General check
•
•
ii.
Phasing check before and after jointing
Continuity check
Oil Filled Cable (275kV & 132kV)
No
Test
1
Cable insulation
resistance test
2
Sheath insulation
test
3
HV pressure test
4
Corrosionresistance
covering test
Oil flow test
5
6
7
Check of gas
constant for
Pressure Tank
Impregnation
coefficient
Details
Limit
The test shall be
conducted for the
conductor using a 10 kV
insulation tester. The
test shall be done for
every span before
jointing works and to be
repeated for the
complete circuit.
Consistent values
between phases
The test shall be
Leakage current
shall be less than 10
conducted for the
sheath using a 10kV DC mA
high voltage test set.
The test shall be done
for every span before
jointing works and to be
repeated for the
completed circuit.
Test voltage applied
No discharge
between conductor and
screen equals to 3.5 Uo
DC for 15 minutes
Test voltage equals 10
No discharge
kV DC applied for 1 min
Measurement of the
pressure drop
Measurement of the
pressure drop at PT
cells
A measured quantity of
oil drawn from the cable
system and the
consequent drop in
pressure noted
Value compared to
the theoretical value
Value compared to
the theoretical value
Impregnation
coefficient shall not
be greater than 16 x
10 exp -6
'
! "#
$ $
8
3.2
Testing
Required
(Cont 2)
iii.
Earthing
resistance test.
Measurement of
earthing resistance
between link box’s
earthing terminal to
earth.
Transition Joint (Hybrid Cable System)
No
Test
1
Cable insulation
resistance test
Details
The test shall be
conducted for the
conductor using a 10kV
insulation tester.
Sheath insulation
test
3
Oil Flow test
4
Check on gas
constant for
pressure tank
Oil test
(Dielectric
Breakdown) BDV
Oil test ( Moisture To be done before
Content)
Jointing
AC voltage test
Cable on soak for 24
hours
5
6
7
Limit
Consistent values
between phases
The test shall be
Leakage current
conducted for the
shall be less than 1
sheath using a 10kV DC mA (measured per
high voltage test set.
span)
The test shall be done
for every span before
jointing and to be
repeated for the
completed circuit.
Measurement of
Value compared to
pressure drop
the theoretical value
Measurement of
Value compared to
pressure drop at PT
the theoretical value
cells
To be done before
> 60kV
jointing
2
iv.
The measured value
shall be less than
3Ω.
< 30ppm
No failure or
breakdown
XLPE Cable (275kV &132kV)
No
Test
1
Cable insulation
resistance test
Details
Limit
The test shall be
conducted for the
conductor using a 10 kV
insulation tester. The
test shall be done for
every span before
jointing works and to be
repeated for the
completed circuit.
Consistent values
between phases
(
! "#
$ $
3.2
Testing
Required
(Cont 3)
f.
2
Sheath insulation
test
The test shall be
conducted for the
sheath using a 10kV DC
high voltage test set.
The test shall be done
for every span before
jointing and to be
repeated for the
completed circuit.
Three phase current of
100 A applied to the
phase conductor. The
resulting sheath current
and voltages to earth at
the cross bonding
positions are measured
3
Cross bonding
test
4
Sheath Voltage
Limiter test
A DC voltage applied
(depend on the type of
SVL) between the
terminals and earth
5
AC voltage test
6
Earthing
resistance test.
Cable on soak for 24
hours
Measurement of
earthing resistance
between link boxes to
earth.
Leakage current
shall be less than 1
mA (measured per
span)
•
The sheath
current value
shall not exceed
the declared
value by > 3%
• The measured
voltage shall not
exceed 65V
IR between SVL and
casing shall be ≥
10MΩ.
The leakage current
shall be compared
against the
manufacturer’s data
sheet and shall not
exceed ± 10%
No failure or
breakdown
The measured value
shall be less than
3Ω.
XLPE Cable (33kV and below, single core cable for transformer cable
tails)
No
Test
1
Cable insulation
resistance test
2
Sheath
insulation test
3
AC voltage test
Details
The test shall be
conducted for the
conductor using a 5 kV
insulation tester
The test shall be
conducted for the sheath
using 10kV DC high
voltage test set.
Cable on soak for 24
hours
Limit
Consistent values
between phases
Leakage current
shall be less than 10
mA
No failure or
breakdown
)
! "#
$ $
3.2
Testing
Required
(Cont 4)
g. Supervisory Telephone Type Pilot Cable.
No
Test
1
Cable insulation
resistance test
2
Conductor
resistance
measurement.
3
High voltage
test.
Details
The insulation
resistance shall be
measured between
each conductor and the
remainder connected
together and to the
aluminium screen and
armour wires. The
measurement shall be
carried out at 500 volts
DC for at least 1 minute.
The conductor
resistance of each core
shall be measured and
recorded.
Each core shall be
tested for 1 minute with
the following DC test
voltages:
• Between the
conductors of each
twin twisted pair –
15kV.
• Between each
conductor and the
remainder
connected together
and to the metallic
screen, armour
wires and earth 25kV.
The above test setup
shall include termination
facilities in the junction
box.
! "#
$ $
Limit
The value shall not be
less than 1 GΩ.
As per declared value.
The leakage current
value shall be less
than 1mA.
h. Optical Fibre Cable laid with Power Cable.
3.2
Testing
Required
(Cont 5)
No
Test
Details
1
Total
A laser source and
Attenuation Test power meter shall be
used for these
attenuation
measurements. End to
end test to check the
continuity of each fibre.
The measurement shall
be done from both ends
and the average
computed. Test shall be
done with two
wavelength, 1310nm and
1550nm.
Limit
The value shall be
less than Calculated
Value.
Formula:
Value < Cxd + Sxn +
Kxk
C=Fibre Cable Lost
(constant)
d=Fibre Cable Length
S=Splice Loss in dB
(constant)
n=Number of splices
K=Connector Loss in
dB (constant)
k=Number of
Connector
C=0.40dB/km at
1310nm wavelength
0.25dB/km at 1550nm
wavelength
S=0.10dB &
K=0.50dB for both
wavelength
2
! "#
$ $
Splice Loss
Test
An optical time domain
The value shall not be
reflectometer (OTDR)
more than 0.10dB.
shall be used for these
attenuation
measurements. The
measurements shall be
recorded by a printer.
The optical loss
measured shall not
exceed the specified
maximum allowable
attenuation for the per
unit loss. Test shall be
done with two
wavelength, 1310nm and
1550nm.
SAT Appendix L: SAT for Primary Injection Tests for CT Circuit
1.0
2.0
3.0
4.0
5.0
Purpose ..................................................................................................................................... 1
Requirement Prior to Primary Injection ..................................................................................... 1
Testing Condition & Restrictions ............................................................................................... 1
Primary Injection Tests ............................................................................................................. 2
Specific Requirement ................................................................................................................ 4
1.0
Purpose
2.0
Requirement
Prior to
Primary
Injection
3.0
Testing
Condition &
Restrictions
The purpose of primary injection for the CT circuits is to:
•
Ensure that the secondary wirings of the CT are correctly connected to its
intended protection scheme.
•
Ensure that the connected CT ratio is as per design requirement.
•
Detect any mistakes in the CT polarity termination.
This test should only be started after the following activities have been
successfully completed:
a.
All wiring activities in the bay under test.
b.
Wiring check as required in Appendix G
c.
CT tests as per Appendix J
d.
Secondary injection of all instruments and relays at both relay and control
panels.
e.
The required CT ratio connection (for multi-ratio CT’s) have been decided
and connected.
f.
Test procedure as per Appendix B shall be available.
The following conditions shall be adhered to during the test:
a.
The minimum primary injection current should be at least 10% of the rated
CT ratio connected.
b.
Phase to ground primary injections shall be conducted first followed by the
phase to phase primary injections.
c.
When primary injection tests are being carried out in a live substation all
necessary isolation shall be documented in the testing procedure.
d.
Primary injection test shall be performed on all CT’s.
e.
Test form as required in Appendix A shall be prepared with the following
additional information:
i.
ii.
iii.
iv.
v.
! "#
CT Ratio
CT Function
Phase Injected
Primary Injection value
Secondary Measurement Result
$ $
4.0
Primary
Injection
Tests
The following primary injection tests shall be conducted:
a. Phase to ground primary injections:
i.
Only the particular core of the phase being tested should be left
connected to its intended function with all other cores of the phase kept
shorted. For example, in diagram Figure O1 below, during primary
injection of CT core R1 the other cores in the phase i.e. R2. R3 and R4
shall be kept shorted.
ii. Measurement of the secondary current shall be taken for all phases and
neutral at point A (MK) and at point B (instrument/relay) as indicated in
Figure O1.
iii. All cores of a phase shall be tested similarly.
b. Phase to phase primary injections:
i.
c.
The secondary current shall be measured for all phases and neutral at
the instrument/relay. For example during a R-Y phase to phase primary
injection measurements are to be taken from points A, B, C and D as
indicated in Figure O2
At least the following tests shall be carried out for (a) and (b) above.
i.
ii.
For Phase to ground – Y-N
For Phase to Phase -- R-Y and B-R
d. For CT’s used for multiple functions, measurements shall be taken at all
components as indicated in Figure O3 below.
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5.0
Specific
Requirement
Following are the specific requirements, to be checked during primary injection
for:
a. High impedance busbar protection current circuit
i.
ii.
Busbar isolator auxiliary contact timing shall be set and tested and
marked permanently as required before the primary injection. Timing
diagram shall be plotted for all isolator’s auxiliary contacts.
For busbar protection current circuit which checks through the busbar
isolator auxiliary contacts, the following shall be confirmed during primary
injection as in Figure O4
• Short-circuiting of the CT when both busbar isolators are open (A).
• Each circuit that checks through isolator auxiliary contact (B) & (C).
b.
Inaccessible CT – For CT’s positioned such that primary injection is not
possible e.g. transformer bushing CT, all circuits involved would then have to
be proved using load current after energizing.
c.
For protection scheme with paralleled CT, e.g. distance protection CT on 1½
breaker scheme using 2 sets of CT for each phase, each CT shall be tested
independently first and then as a composite. The following example illustrates
this requirement as in Figure O5.
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SAT Appendix M: SAT for Secondary Injection Tests for Voltage Circuit
1.0
2.0
3.0
4.0
Purpose ..................................................................................................................................... 1
Requirement Prior to Voltage Circuit Secondary Injection........................................................ 1
Testing Condition & Restrictions ............................................................................................... 1
Secondary Voltage Injection Tests ........................................................................................... 2
1.0
Purpose
The purpose of secondary injection test for the voltage circuits are to:
•
•
2.0
Requirement
Prior to
Voltage
Circuit
Secondary
Injection
Ensure that the secondary cores of the CVT/PT are correctly connected to its
intended protection relay, instrument and recorders.
To ensure correct phase connections from CVT/PT to its intended protection
relay, instrument and recorders.
This test should only be started after the following activities have been
successfully completed:
a. All wiring activities in the bay under test.
b. Wiring check as required in Appendix G
c.
CVT/PT tests as per Appendix J
d. Secondary injection of all instruments and relays at both relay and control
panels.
e. Test procedure as per Appendix B shall be made available.
3.0
Testing
Condition &
Restrictions
The following conditions shall be adhered to during the test:
a. All precaution to avoid back energizing of the CVT/PT shall be taken.
b. Three phase voltage source, with different voltage magnitudes for each R, Y,
and B e.g. 63.5, 60, 57 respectively shall be used to prove all VT circuits.
c.
When this test is performed in a live substation all necessary isolation shall
be documented in the testing procedure.
d. Each voltage circuit from the CVT/PT shall be tested separately up to the
protection relay, instrument and recorders.
e. All voltage circuits in the plant shall be tested e.g. voltage selection,
synchronizing circuits etc.
f.
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Test form as required in Appendix A shall be prepared with the following
additional information:
i. VT circuit function
ii. Injection value at source
iii. Voltage measurement at protection relays, instruments and recorders.
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4.0
Secondary
Voltage
Injection
Tests
The following example as illustrated in Figure P1 shows the method of secondary
voltage injection tests:
a. Inject three phase test voltage at point X for circuit 1 and measure at points
A, B, C and D.
b. Repeat the test for injection at point Y for circuit 2.
c.
Measurements shall be made for all voltage circuits.
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SAT Appendix N: SAT for Protection and Control Scheme
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1.0 Purpose
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To provide general SAT requirements on conventional or digital substations when
carrying test on the various protection and control schemes.
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2.0 Definitions
No.
1.
Name
Negative check
2.
Positive check
3.
4.
Switching devices
or switchgears
CECOMS
5.
EGW
6.
ESM
7.
GSO
8.
HMI
9.
ICT
10.
IED
11.
NCC
12.
NLDC
13.
RTU
14.
SCADA
15.
SGW
Description
A test performed to check the incomplete
condition shall not cause operation.
A test performed to check the successful
operation of the intended function.
Circuit Breaker, Busbar Isolator, and Line
Isolator & Earth Switch.
Centralized Equipment Condition and Online
Monitoring System (CECOMS) – The TNB Grid
enterprise monitoring system, for monitoring of
substation equipment as part of maintenance
activity.
Enterprise Gateway – Device that forms the
interface between the IEC 61850 IEDs,
including other smart devices within a
substation and the enterprise monitoring
system, namely CECOMS.
Managed Ethernet Switch – Layer 2 network
device. Multiple ESMs are used to form the
IEC 61850 communication network in a digital
substation. ESM is also used for RTU to
communicate with Modbus TCP transducer.
Grid System Operator – The entity that
manages the grid power system via the
SCADA system at NLDC.
Human Machine Interface - The main user
interface for station level monitoring and
control of the power system and substation
equipment within a digital substation.
Information Communication Technology – TNB
ICT Division is responsible to provide
telecommunication services for SCADA and
protection applications.
Intelligent Electronic Device – Microprocessorbased controller of power system equipment,
primarily used as digital protective relay in a
digital substation.
Network Control Centre – Generic term for
NLDC.
National Load Dispatch Centre – The grid NCC
with SCADA master facilities operated by
GSO.
Remote Terminal Unit – Device that interfaces
with NLDC SCADA system in a conventional
substation to provide network level control and
monitoring for the substation.
Supervisory Control and Data Acquisition –
SCADA system is used for managing the grid
power system. It consists of SCADA master,
operated by GSO at NLDC, and remote
devices at substations (RTU or SGW),
maintained by TNB Grid Division. SCADA
master and remote devices are connected by
telecommunication system managed by TNB
ICT Division.
SCADA Gateway – Device that forms the
interface between the IEC 61850 IEDs within a
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16.
STS
digital substation and the NCC.
Substation Time Server – Device that provides
time-synchronization function for all IEC 61850
IEDs and client devices (SGW, EGW and HMI)
in a digital substation.
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3.0 General
Requirement
General requirement for Protection and Control scheme test:
a. All schematic / detail wiring drawings shall be as per TNB approved
conceptual / scheme drawing. Testing shall only be carried out based on the
schematic drawings and not based on an individual’s past experience. All
schemes available in the plant as indicated in the schematic drawing shall be
tested. (Note: if any design error discovered during testing, tester is required
to record in Master Defect List)
b. Schematic drawings of a scheme being tested shall be highlighted with a
fluorescent marker.
c.
For all protection schemes e.g. distance protection, auto-reclose etc. a
conjunctive test report shall be made available.
d. For installation with Global Positioning System (GPS) facility, it shall also be
tested. For Digital Substation, time synchronization test using Substation
Time Server (STS) shall also be covered.
e. Both the positive and negative checks of a logic circuit shall be checked and
documented. For example, as per figure Q1 to test the operation of relay X,
all the following tests shall be performed:
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With contacts A, B, C and D closed relay shall operate – Positive check
Open contact D and the relay shall reset – Negative check
Close contact D and open contact C and the relay shall reset – Negative
check
Close contact C and the relay shall operate again – Positive check
Open contact B, relay should remain energized – Positive check
Open contact A (with B still open) relay shall reset – Negative check
Close B and relay shall energize once again – Positive check
The above test should be documented as per the table below.
Status of Logic
No.
A
B
C
D
1
Close
Close
Close
Close
2
Close
Close
Close
Open
3
Close
Close
Close
Close
4
Close
Close
Open
Close
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Relay X
Operate
Reset
Operate
Reset
5
6
7
8
Close
Close
Open
Open
Close
Open
Open
Close
Close
Close
Close
Close
Close
Close
Close
Close
Operate
Operate
Reset
Operate
Once the above test on relay X is completed, the rest of the test to check the
trip (E) and alarm (F) signal from the relay can be performed by activating the
relay X by giving a direct positive to point D.
Only after all the above tests, the circuit is proven to be in order. This concept
shall be applied for any logic test especially for control circuit and interlock
circuits in particular.
g.
For Digital Substation, software based control and interlocking logic shall be
tested using the similar concept as the above table.
h.
For the following protection scheme test, secondary injection shall be carried
out from the terminal blocks instead of test terminal blocks:
o
o
o
o
o
o
o
Protection trip test.
Auto-reclose test.
Signaling check to control panel facia indication/counter
Signaling check to SCADA facility (RTU/SCADA Gateway)
Signaling check to HMI (for Digital Substation)
Signaling check to EGW/CECOMS
Signaling check to digital fault recorder
i.
For switching devices (isolator & CB) opening operation tests
(supervisory/station/bay), all applicable switching devices in the plant shall be
kept in the closed position, only the intended switching device shall Open.
k.
For switching devices (isolator & CB) closing operation tests
(supervisory/station/bay), all applicable switching devices in the plant shall be
kept in the opened position, only the intended switching device shall Close.
l.
Isolator position indication shall be tested such that Close status is indicated
when isolator is fully closed and Open status is indicated when isolator is fully
opened.
m. For interlock check involving isolators position, test shall be made to prove
interlock is permitted only when the isolator is fully open or close.
n. Test the DC supply segregation of each scheme. Each individual scheme
shall be tested with only its scheme DC supply kept ‘ON’. For example:
i.
ii.
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During interlock test, only the DC supply for the control scheme shall be
kept ‘ON’ and all other DC supply e.g. protection DC kept ‘OFF’.
During voltage selection test, only the DC supply of the voltage selection
scheme shall be kept ‘ON’ and all other DC of all bays shall be ‘OFF’.
o. Non-protection trip test e.g. transformer guard, SF6 stage 2 tripping of CB or
GIS busbar shall also be performed and recorded.
p. For switchgear position indication check, test that the position indication e.g.
at control panel or NLDC, is only given when the switchgear is fully closed or
open.
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q. For all interlock tests, test that the interlock operation is permitted when the
switchgears is fully open or fully closed.
r.
Scheme tests for protection trip, alarm, disturbance recorder, SCADA facility,
HMI (Digital Substation) and EGW shall be carried out by actual simulation of
the signal. Contact shorting to simulate a test signal is to be avoided unless
there are no other means of simulating the test signal.
s.
For each test, the signal simulation method and the result of the simulation
shall be stated in the test form.
t.
For signal simulation by shorting, the shorting shall be carried out at the point
nearest to the component under test and the terminal shall be stated in the
test form.
u. Check all relay, indications flag, fascia, HMI, SCADA, and EGW description
are in order, accurate and clearly explaining the intended purpose as per Grid
Substation Signaling Requirements (GTS-GSE-SSR).
v.
Detailed test procedure with relevant diagrams, test combinations shall be
provided for all scheme tests. All scheme tests shall be documented in detail.
Test conditions and its results shall be easily understood.
w. Any modification on a scheme that has been tested shall subject that
particular scheme to a complete retest.
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Protection trip test shall be performed with the following arrangement:
4.0 Protection
Trip Tests
All breakers in the plant should be kept in closed position during the trip test.
Only intended breaker(s) to trip.
0
Trip test shall be performed using the actual CB (not dummy breaker). For
single pole CB operation, ensure the single pole tripping signal trip the
correct phase (applicable for 275kV and above OHL only).
To test the DC supply segregation of the tripping scheme, only the protection
DC supply of the trip coil under test is kept on. All other DC supply e.g.
annunciator, control, indication, shall be switched off.
(
During each trip test the performance of CB, all associated indication and
events shall be recorded e.g. counter, relay flag, SCADA facility, HMI, EGW
and fascia.
Isolation link facility (Test terminal block, Group Isolation Link Analog and
Digital, and Trip Link) shall be tested during trip test. Direct tripping and
tripping via master trip shall be tested. Analog Group Isolation Link is only
applicable for 275kV and above OHL and cable.
For trip scheme with two trip coil, the tripping shall be repeated for each coil
with the other coil isolated.
2
Following is the example of a busbar protection trip test performed for a
double busbar configuration as per Figure Q2 The method used in this
example shall be the guiding principle when performing any trip test for other
types of protection scheme:
1
1
1
1
1
Both positive and negative checks as described in Appendix N shall be
performed.
Record all associated indication and events for each trip test.
Record counter operation for each trip test
Test isolation link (Test terminal block, Group Isolation Link, and Trip
Link) functionality
Check all relay indications are in order so that a faulted busbar phase
and its zone can be easily identified.
Perform trip test for each trip coil independently. When performing trip
test on trip coil 1, trip coil 2 of all breaker shall be isolated and vice versa.
For main and duplicate busbar protection scheme each main and
duplicate scheme shall be tested independently. When performing trip
test for the main, the DC supply of the duplicate scheme shall be
switched off.
All the above tests shall be documented.
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4.0 Protection
Trip Tests
(Cont. 1)
/
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2
.
.0
1
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1
1
The following table lists examples of busbar protection trip test results with
all trip isolation link not removed.
No
1
2
3
4
5
6
7.
Test Condition With
Trip
Link
Not
Removed
All feeder on Main
busbar (M1 & M2) and
all CB closed
All feeder on Main
busbar (M1 & M2) and
all CB closed
All feeder on Main
busbar (M1 & M2) and
all CB closed
All feeder on Reserve
busbar and all CB
closed
All feeder on Reserve
busbar and all CB
closed
All feeder on Reserve
busbar and all CB
closed
Switch off Main 1.
All feeders on Main 1
Trip Test simulated
Result
Initiate check zone
followed by reserve
busbar trip
Initiate check zone
followed by M1 busbar
trip
Initiate check zone
followed by M2 busbar
trip
Initiate check zone
followed by M1 busbar
trip
Initiate check zone
followed by Main 2
busbar trip
Initiate check zone
followed by Reserve
busbar trip
Initiate check zone
followed by Main 1
B/C trip
Feeder 1, 2,
B/S and B/C
trip
Feeder 3, 4
and B/S trip
B/C trip
B/C trip
Feeder 1,2,3,4
and B/C trip
No trip.
Similar table shall be provided for trip test with trip isolation facility been
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removed.
The following table lists examples of protection trip test results.
4.0 Protection
Trip Tests
(Cont. 2)
Protection Trip test
No
Function
tested
Simulation Method
1
Overcurrent
protection
Secondary injection
of phase to phase
fault. (R-Y)
2
Main 1 Busbar
protection
Secondary injection
of busbar protection
relay
CB tripped, Fascia,
Counter, relay
Indication, HMI, SCADA
facility and
EGW/CECOMS
CB tripped:
• HV CB
• LV CB
Relay indication: R, Y
Counter (CBM/physical):
incremented
Fascia (conventional):
• Overcurrent operated
• Master trip.
Fascia (DS):
• Protection Trip
CB tripped:
• All feeders on Main 1
• Bus-section
• Bus-coupler
Counter(CBM/physical):
incremented
Fascia (conventional):
• Main
Busbar
operated
• Master trip on all
feeders on Main 1
Fascia (DS):
• Protection Trip on all
feeders on Main 1
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5.0 Annunciator/
Alarm Test
In addition to complete alarm and annunciator tests, the following shall also be
carried out and recorded:
a. Test the DC supply segregation from the annunciator scheme. Test the
annunciator DC supply is independent of all other DC source e.g. protection,
control etc.
b. Ensure lamp test function is working properly at control panel and
annunciator.
c.
Test functions such as “ACKNOWLEDGE” and “RESET” are functioning
properly for all bays.
d. Test functionality of the annunciator scheme when the annunciator DC supply
fail or its DC-DC converter fails.
e. Test functionality of all discrepancy indication and its alarm operation.
f.
Test “ATTEND/ UNATTEND” function is operating properly.
g. All alarm signals to fascia and flag relay shall be tested.
The following table lists some examples of conventional annunciator signal
tests.
Annunciator alarm test
No Function
Simulation Method
tested
1
Bucholz Alarm
Press test button at Bucholz
relay
2
Winding Temp Turning test handle at winding
Trip
temperature indicator
3
Overcurrent
protection
Overcurrent
protection
Overcurrent
relay faulty
CB SF6 stage
1 alarm
4
5
6
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Secondary injection of phaseto-phase fault.
Secondary injection of earth
fault.
Isolate DC supply to relay
Short X1 and X2 terminal at
pressure gauge
Result/Remark
Buchholz Alarm
Winding temp trip.
Master
trip
operated.
Overcurrent op.
Master trip op.
Overcurrent op.
Master trip op.
Overcurrent relay
faulty
SF6 stage 1 alarm
6.0 General
Requirement
for System
Communication
and Clients
Test
a. System test covers validation of communication, SCADA facility, HMI (for
Digital Substation), and EGW. The tests shall be coordinated and initiated by
PM with relevant parties.
b. SCADA test shall include RTU or SCADA Gateway. All SCADA facilities shall
be tested up to the regional or national control center (NLDC).
c.
For substations equipped with RTUs, the SAT shall be carried out to verify the
following:i.
ii.
SCADA functionality test:
• Between SCADA Interface Panel(s) and Plant
• Between RTU and SCADA Interface Panel(s) (Local Test & Physical
Inspection)
• Between SIP and Control Centre
• Between Control Center and Plant
Conjunctive test: Protection Scheme Test
d. For Digital Substations equipped with SCADA Gateway (SGW), the SAT shall
be carried out to verify the following:i.
ii.
e.
6.1 SCADA
Facility Test
SCADA functionality test:
• Between Source (Plant/Non-IEC 61850 relays) and IOIED/BCU
• Between IED and Control Center
• Between Source (Plant/Non-IEC 61850 relays) and Control Center
Conjunctive test: Protection Scheme Test
The test results shall be recorded in the relevant checklist
a. SCADA operation and control circuit
i.
Test all switchgear operation from NLDC both under supervisory (”positive
check”) and remote/station (“negative check”) modes.
ii.
For switchgear opening tests it shall be conducted under the following
conditions:• All applicable switchgear shall be kept in the closed position. Only the
intended switchgear shall open after the test.
• All other applicable switchgear shall be kept in the open position. No
switchgear shall close during this open test.
iii. For switchgear closing tests it shall be conducted under the following
conditions: • All applicable switchgear shall be kept in the open position. Only the
intended switchgear shall close after the test.
• All other applicable switchgear shall be kept in the close position. No
switchgear shall open during this closing test.
For CB with synchronising facility, all combination of synchronised closing e.g.
live-line live-bus, dead-line dead-bus, live-line dead-bus, dead-line live bus,
including the synch bypass scheme shall be tested.
For transformers tap changers control, perform raise and lower tap by
• Selecting supervisory control with manual operation (“positive check”)
• Selecting supervisory control with auto operation (“negative check”)
b. SCADA signal point to point test
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c.
i.
All signals to NLDC shall be tested.
i.
All alarms and indications shall be initiated from the source by actual
operation or injection. Shorting of contacts is only allowed at the source
end when the actual operation cannot be simulated.
SCADA switching devices position indication.
All switchgear position indication shall be tested.
For position indication check involving isolators position, test shall be made
to prove correct position indication is given only when the isolator is fully
open or fully close. Testing to be carried out by actual operation of
switchgear.
d. Sequence of event validation test shall be performed to validate correct
events, correct sequence, and time tagging accuracy of events reported by
SGW/RTU. This test is to be conducted together with all the scheme tests as
listed in this appendix.
e. Metering/instrumentation for substation with RTU facility is tested by
secondary injection from control panel and measure at SCADA interface panel
and verified at relevant control center and EGW. Verify that the measurement
readings at meter, control center and EGW are consistent. Record the
secondary injection value and any measurement or reading made.
f.
NLDC redundancy (main/standby) communication test
i. Manual switchover – NLDC SCADA Engineer to switch from main to
standby channel and vice versa
ii. Automatic switchover – Simulate communication breakdown on main
channel and ensure automatic switchover to standby channel and vice
versa
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a. HMI operation and control circuit
6.2 HMI Test
i.
Test all switchgear operation from HMI under station with supervisory off
(”positive check”) and station with supervisory on (“negative check”) modes.
ii. For switchgear opening tests it shall be conducted under the following
conditions:• All applicable switchgear shall be kept in the closed position. Only the
intended switchgear shall open after the test.
• All applicable other switchgear shall be kept in the open position. No
switchgear shall close during this open test.
iii. For switchgear closing tests it shall be conducted under the following
conditions:• All applicable switchgear shall be kept in the open position. Only the
intended switchgear shall close after the test.
• All other applicable switchgear shall be kept in the closed position. No
switchgear shall open during this closing test.
For transformers tap changers control, perform raise and lower tap by
• Selecting station control with manual operation (“positive check”)
• Selecting station control with auto operation (“negative check”)
b. HMI signal point to point test
i. All signals to HMI shall be tested.
ii. All alarms and indications shall be initiated from the source by actual
operation or injection. Shorting of contacts is only allowed at the source
end when the actual operation cannot be simulated.
c.
HMI switching devices position indication.
All switchgear position indication shall be tested.
For position indication check involving isolators position, test shall be made
to prove correct position indication is given only when the isolator is fully
open or fully close. Testing to be carried out by actual operation of
switchgear.
d.
Sequence of event validation test shall be performed to validate correct events,
correct sequence, correct addressing (Information Object Address/IOA) and
time tagging accuracy of events reported by HMI (refer to the diagram below).
This test is to be conducted together with all the scheme tests as listed in this
appendix.
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e. For Digital Substation metering/instrumentation test, perform secondary
injection at Bay Controller for bay measurement and Station IOIED for Busbar
measurement and observe the measurements at:•
•
•
•
•
Control Centre
HMI
EGW
Bay Controller/Station IOIED
Digital Instrument Meter
( 3
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1
( '
Verify that the measurements are consistent.
f.
(
All signals configured shall appear in the appropriate HMI displays listed below
as per HMI GUI Design Guideline
i. Dashboard
ii. Station Overview/System Architecture page
iii. Single Line Diagram page
iv. Bay Diagram page
• Bay Single Line Diagram
• Bay Fascia
• Analog Measurement
• Synchronisation
• Interlock
v. Event page
vi. Alarm page
vii. Station Fascia page
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This test is to be assisted by TNB. All verification is done using UIP (Universal
Interface Platform).
6.3 Enterprise
Gateway
(EGW) Test
a. EGW signal point to point test
i.
All signals to SCADA and HMI as per signal list shall be tested to reach to
EGW.
ii. All alarms and indications shall be initiated from the source by actual
operation or injection. Shorting of contacts is only allowed at the source
end when the actual operation cannot be simulated.
b.
EGW switching devices position indication.
All switchgear position indication shall be tested.
For position indication check involving isolators position, test shall be made
to prove correct position indication is given only when the isolator is fully
open or fully close. Testing to be carried out by actual operation of
switchgear.
c.
Sequence of event validation test shall be performed to validate correct
events, correct sequence, and time tagging accuracy of events reported by
EGW. This test is to be conducted together with all the scheme tests as listed
in this appendix.
d. For Digital Substation metering/instrumentation test, perform secondary
injection at Bay Controller for bay measurement and Station IOIED for Busbar
measurement and observe the measurements at:•
•
•
•
•
Control Centre
HMI
EGW
Bay Controller/Station IOIED
Digital Instrument Meter
Record the secondary injection value and any measurement or reading made.
Verify that the measurements are consistent.
e. For Digital Substation, MMS file transfer service shall be tested. Fault
record shall be retrieved by EGW upon fault record made, triggered via
MMS by relay.
6.4
Communicatio
n Test
a.
All device communication settings e.g. IP Address, Subnet Address and
Multicast GOOSE Address shall be configured as per approved documents
(approved drawings, Design Verification results)
b. Validation of Managed Ethernet Switches (ESM):
iii.
Port mirror settings
iv.
RSTP redundancy test
v.
Port configuration and connection
6.5 Substation
Time Server
a. Time synchronization function for all devices:
i. No time sync error at IEDs
ii. Event time stamp within 1ms error. This test can be performed during client
point-to-point test
iii. Resynchronization between IED and STS. This test can be performed by
disconnecting the STS from the network and reconnecting it.
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b. GPS antenna installation
i. Located at optimum location
• Vertical position
• Unobstructed view of the sky
• At high as possible
• Conduit path (along the wall)
ii. Locked to optimum number of satellites
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a.
7.0 Digital Fault
Recorder
The recorder shall be set and configured as per Product Guidebook
i.
Line parameters i.e. length and impedance (Reference to Computer
Aided Protection Engineering data)
ii. CT and VT ratio
iii. User name, Password, station number (if applicable) etc.
iv. Communication settings and any other information required to
communicate with the recorder remotely.
v. Recorder setting details. e.g. pre-triggering time, post-triggering time,
triggering threshold, weight value (where applicable), auto-polling/autocalling (where applicable)
vi. Digital and Analog channel name
b.
For recorder, test form as required in Appendix A shall be prepared with all
the additional information as per (a).
c.
For recorders, secondary injection shall be carried out to verify
All analog inputs for pick-up values
Directional test (confirm CT connection and star point as per TNB
standard application document)
d.
Test all digital signal inputs to the recorder by simulation at the signal source
point. Verify the signals for:
Triggering on pick-up
Triggering to store event
Cross triggering between subunits (where applicable)
e.
For Digital Substation with virtual inputs, verify correct subscription to GOOSE
message from each IED by simulation at the signal source point. Verify the
signals for:
Trigger on pick-up
Trigger to store event
Cross triggering between sub-units (where applicable)
f. Test all alarm signals from the recorder.
g. The Global Positioning System (GPS) facility for time synchronization shall
also be tested.
h. At least the following tests shall be performed under the Scheme test:
1
The consistency of digital signal initiation from relay to recorder, SCADA
and facia shall be checked and verified during auto-reclose test with
actual circuit breaker (See Section 8.0 – Auto-reclose).
During this test at least the secondary injection voltage source shall be
connected to the recorder in parallel.
For line differential protections, the secondary current injection to the
relay shall be wired in series to the recorder.
For recorders installed on transformers and power cables without autoreclose facility, the above test shall be carried out with appropriate
modifications
Test the remote communication functions of the recorder e.g. directory view, event
file retrieval, auto-polling/auto-calling, remote setting configuration and manual
triggering. This test must be conducted in TNB Operational Network.
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Protection and Control Scheme shall be tested and verified upon completion of
secondary injection as per Appendix I, and can be done together or before
Primary injection test for VT and CT as per Appendix L or M, stability test as per
Appendix O whenever required.
8.0 Protection
and Control
Scheme
Test form as required in Appendix A shall be prepared for all the related tests.
The following test shall be performed to commission the differential protection
scheme:
8.1 Line
Differential
Protection
Scheme
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. AR (applicable for line application) and CBF initiation test
i. All phase to phase fault
ii. All phase to ground fault
iii. Three phase fault
c.
Lockout Intertrip test to verify lock out operation and blocking of auto reclose
scheme at remote end when local end close onto fault via internal Line
Differential communication
d. End to end communication test (single end injection) to verify intertripping
function and measurement available at remote end. For 3-terminal
application, this test shall be carried out at all ends, e.g A to B, A to C and B
to C.
e. DC System of the protection scheme
f.
Perform trip test as per Section 4.0
The following test shall be performed to commission pilot wire protection scheme:
8.2 Pilot Wire
Protection
Scheme
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation
b. For pilot wire the following test shall be performed on every core:
Continuity test
Insulation resistance
Pilot resistance measurement
c.
For pilot wire supervision scheme, the following test shall be performed:
Short-circuit at remote end
Open-circuit at remote end
Wire crossing at remote end
For all the above conditions, the relay shall be able to detect and initiate the
appropriate alarm.
d. Test the functionality of the Overcurrent check scheme
e. DC System of the protection scheme.
f.
Perform trip test as per Section 4.0
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The following test shall be performed to commission the distance protection
scheme:
8.3 Distance
Protection
Scheme
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. AR (applicable for line application) and CBF initiation test
i. All phase to phase fault
ii. All phase to ground fault
iii. Three phase fault
8.4 AutoReclose and
Synchronizing
Check Scheme
c.
DC System of the protection scheme.
d.
Perform trip test as per Section 4.0
The following test shall be performed to commission the Autoreclose and
Synchronizing protection scheme
a.
Any blocking signal to the auto-reclose scheme from main protection shall be
tested by simulating the signal at the source point of the signal.
b. Auto-reclose test shall be performed with all relays e.g. Current Differential,
and being set with the final settings.
c. During the auto-reclose simulation test, the synchronising condition shall be
achieved by actual injection of voltage to the CBM relay.
d. Where main and duplicate protection is used, the whole test shall be repeated
for both protections.
e. During all auto-reclose tests, the following signals shall be monitored and
recorded.
Auto-reclose initiate signal from the main protection relay
Block auto-reclose hardwire signal from the main protection relay
Alarm initiated at SCADA, HMI, and EGW
1 Alarm initiated at fascia
1 All trip and closing signals
1 All indication at main protection relay and AR relay
f.
Auto-reclose test for selected faults shall be performed under the following
conditions (if the functions are available) for all combination of phase to
ground fault, phase to phase fault or three phase faults accordingly
1
1
1
1
Auto reclose switch OFF
Auto reclose switch ON – DAR only with sync OK
Auto reclose switch ON – DAR only with sync fail
Auto reclose switch ON – SPAR & DAR (evolving faults) with sync OK
Auto reclose switch ON – SPAR & DAR (evolving faults) with sync fail
Auto reclose switch ON – SPAR & DAR (evolving faults) with sync OK
and with external A/R blocking signal
Repeat ii-vi with Auto reclose switch selection to 3 and 1+3
g. Test the A/R scheme is not initiated if the CB is initially open.
h. Test the A/R scheme with CB closing circuit isolated.
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i.
Test the “Sync. Fail timer scheme”.
j.
During the auto-reclose test, timing of the following signals shall be monitored
and documented for selected faults:
Measure length of A/R close pulse to the CB closing coil
Measure reclaim time
Measure SPAR dead time
1
Measure DAR dead time
1
Measure sync fail timer
k. Upon successful completion of all above tests, tests as per the Table below
shall be repeated with the actual CB and disturbance recorder connected.
Main Protection
No Fault Injected
1
R-N
2
B-N
3
l.
4
5
R-N followed by B-N
(evolving fault)
R-Y
Y-B
6
7
B-R
R-N
8
9
10
B-N
R-N followed by R-N
immediately upon autoreclosing (TOR)
Y-N
11
Y-N
Scheme condition to be tested
Successful single pole A/R (SPAR)
Successful SPAR followed by second
fault in 1 sec of reclaim time
R-N fault followed by evolving fault on YN fault at 650 ms
Successful delay A/R (DAR)
Successful DAR followed by second fault
in 20th sec of reclaim time
SOTF
φ-N, fault immediately after Manual Close
Of CB
φ-N, fault with CB initially open
TOR (Expected local and remote end
lockout. Remote end Auto-reclose will be
interrupted)
Auto Reclose switched to OFF resulting in
Three-pole tripping with lockout operation.
Auto Reclose fail resulting in Three-pole
tripping without lockout operation
Confirm any backup protection not initiate Auto Reclose
m. For 1½ breaker system, all tests, which are applicable, shall be carried out
including but not limited to:
• Trip on Reclose (TOR) (TOR from bus circuit breaker shall interrupt
operation of center circuit breaker auto-reclosing)
• Priority release scheme to be tested but not limited as per the table below
No
1
Fault
Injected
R-N
Bus Auto
Reclose
1+3
Center Auto
Reclose
1+3
2
Y-B
1+3
1+3
3
RYB
1+3
1+3
4
R-N
OFF
1+3
Scheme condition to be
tested
Single phase to ground
fault (SPAR). Expected
dead time difference of 1
sec between bus and
center CB.
Phase-to-phase
fault
(DAR). Expected dead
time difference of 1 sec
between bus and center
CB.
Three-phase fault. No
AR.
Center CB Auto-Reclose
on
SPAR.
Expected
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5
Y-B
OFF
1+3
6
Y-N
1+3
1+3
7
B-N
1+3
1+3
Center CB dead time as
per
setting
without
extension.
Center CB Auto-Reclose
on
DAR.
Expected
Center CB dead time as
per
setting
without
extension.
Bus
CB
in
open
condition. Center CB
Auto-Reclose on SPAR.
Expected Center CB
dead time as per setting
without extension.
Simulate Bus CB fail to
close. Expected dead
time difference of 1 sec
between bus and center
CB.
At least the following combinations shall be tested
• Each CB individually using dummy breaker
• Both CBs simultaneously using actual breaker
n.
8.5 Thermal
Overload
Function
DC system of the protection scheme.
The following test shall be performed to commission the thermal overload
protection scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. DC system of the protection scheme.
c.
8.6
Transformer
/Reactor Bias
Differential
Protection
Scheme
Perform trip test as per Section 4.0 to validate there is no tripping circuit
wired as per design.
The following test shall be performed to commission the bias differential protection
scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. DC system of the protection scheme.
c.
Perform trip test as per Section 4.0
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8.7 Transformer
/ Reactor High
Impedance
Protection and
Restricted Earth
Fault Scheme
8.8
Overcurrent
Protection
Scheme
The following test shall be performed to commission the high impedance
protection scheme:
a.
Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b.
DC system of the protection scheme.
c.
Perform protection trip test as per section 4.0.
The following test shall be performed to commission the Overcurrent protection
scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. DC system of the protection scheme.
c.
8.9 SBEF
Protection
Scheme
Perform protection trip test as per section 4.
The following test shall be performed to commission the Standby Earth Fault
(SBEF) protection scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. DC system of the protection scheme. E.g. SBEF DC supply shall be from the
respective Transformer LV relay panels. (not B/S LV panel).
c.
Perform trip test.
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8.10 High
Impedance
Busbar
Protection
Scheme
The following test shall be performed to commission a busbar high impedance
protection scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. For CT supervision operation test, verify
Alarm operation
Current circuit shorting and no operation
c.
For numerical high impedance relay with external CT shorting using bi-stable
relay, verify the LED “CT Supervision” at main relay reset upon bi-stable relay
reset (CT shorting removed).
d. Test the busbar protection ‘in-service’ & ‘out of service’ facility.
e. Perform BDACS (Busbar Disconnector Auxiliary Contact Supervision) for all
feeders.
f.
CBF Stage 2 initiation to operate correct busbar zone.
g. Verify that during live transfer, busbar protection must be allowed to trip the
bus coupler and/or bus section breakers based on busbar configuration.
h. DC system of the protection scheme.
i.
Perform busbar protection trip test as per section 4.0.
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The following test shall be performed to commission a busbar low impedance
protection scheme: :
8.11 Low
Impedance
Busbar
Protection
Scheme
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. CB/Isolator status check to confirm correct auxiliary contact are wired.
Simulate isolator invalid status and bridging condition to verify alarm is sent
after time delay.
c.
For Bus Coupler/Bus Section Dead Zone Protection function, simulate Bus
Coupler/Bus Section in open position and simulate fault between CT and CB.
Verify the correct busbar zone operation.
d. CBF Stage 2 initiation to operate correct busbar zone
e. For 1HCB End Fault Protection function, verify intertrip and CBF initiation
send to remote end. It shall be further verify that for 500kV system, the
initiation shall be performed via two teleprotection channel.
f.
Test the busbar protection ‘in-service’ & ‘out of service’ facility.
g. DC system of the protection scheme
h. Perform protection trip test as per section 4.0
8.12 Breaker
Failure
Protection
Scheme
The following test shall be performed to commission the Circuit Breaker Failure
protection scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. CBF initiation shall be performed with all relays which initiating CBF e.g.
Current Differential, and being set with the final settings
c.
Simulate AR in 3 Pole position and simulate a single phase fault condition.
Verify CBF initiation are resulted in all 3 phases
d. Simulate AR failed and simulate a single phase fault condition. Verify CBF
initiation are resulted in all 3 phases
e. DC system of the breaker failure scheme.
f.
Perform trip test as per section 4.0.
g. All requirements for busbar protection trip test shall be validated.
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8.13 Manual
Synchronizing
Check Scheme
The following test shall be performed to commission the synchronizing scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b.
To verify all voltage circuits.
c. Secondary injection validation on the synchroscope
d. Test any DC interlock priority scheme. Test that only one bay can be
synchronized at a time.
e. Synchronized closing of CB shall be tested from remote and supervisory.
f.
For supervisory control, the test shall be carried out first by initiating control
(by shorting) from the SCADA Interface Panel (RTU) followed by initiation
test from the Control Center after communications to the Control Center have
been established.
g. The following conditions of CB closing shall be tested:
1
Live Line - Live Bus (Synchronized closing)
Live Line – Dead Bus (Voltage checked closing)
Dead Line – Live Bus (Voltage checked closing)
Dead Line – Dead Bus (Voltage checked closing)
h. Any synchronising bypass or override scheme (where applicable) shall be
tested.
i.
CVT MCB trip and CVT isolator open blocking signal from the source ends
shall be tested for blocking the voltage check closing function. Verify that
synchronizing closing is not affected.
j.
All necessary tests to prove that any component or relay failure in the
scheme do not cause any of the CVT’s to be back energized shall be
performed.
k.
The performance of the synchronizing scheme shall also be tested during live
transfer condition with synchronized closing.
l.
All possible conditions tested shall be clearly mentioned in the test report.
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8.14
Demand/Load
Shedding
Scheme
The following test shall be performed to commission the Demand Shedding
scheme:
a. Secondary injection as per Appendix I to test alarm (fascia HV panel and LV
panel, HMI, EGW), SCADA and counter operation.
b.
Verify On/Off Selector switch functionality. Ensure function inhibited when
switch is turned off (DC supply to relay remain intact).
c.
Verify FR (relay fault record) cross triggering function by simulation.
d. Verify external undervoltage blocking function for UV element
e. DC system of the protection scheme.
f.
8.15 Automatic
Voltage Regulation
Scheme
Perform trip test as per Section 4.0. Ensure transformers tripping circuit is
wired based on paralleling capability grouping.
The following test shall be performed to commission the AVR scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. Confirm single phase voltage and current tapped accordingly as per
setting requirement
c.
Verify maximum and minimum Tap Change Position as per actual OLTC.
Simulate all the position and to confirm AVR reads the correct tap
position.
d. Confirm Raise and Lower operation to RTCC Panel
e. Verify the actual maximum running time of OLTC for one tap changing
time and set the AVR accordingly. Simulate a longer operation time and
verify alarm is sent.
f.
Verify over voltage/under voltage blocking for any raise or lower operation
at OLTC.
g. Verify manual AVR control from HMI with CAS (Control Authority) Switch
set to ‘Station’.
h. Verify manual AVR control from supervisory with CAS (Control Authority)
Switch set to ‘Supervisory’.
i.
Verify emergency operation by simulation AVR fail and tap changing
operation can be performed at RTCC panel with physical Raise and
Lower Buttons.
j.
Emergency Stop button to stop tap changing operation (at RTCC panel).
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The following test shall be performed to commission the PD scheme:
8.16 Pole
Discrepancy
Scheme
a. Simulate CB single pole, 2 pole and 3 pole opening and verify PD operation
b. Timing Test and CB Auxiliary contact (NO / NC) verification
c.
Test alarm (fascia, HMI, EGW), SCADA and counter operation
d. Protection trip test as per section 4.0
8.17 Unbalanced
Capbank
Protection
Scheme
The following test shall be performed to commission the Unbalanced Capbank
Protection scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. Perform trip test as per Section 4.0
The following test shall be performed to commission the Overload Capbank
Protection scheme:
8.18 Overload
Capbank
Protection
Scheme
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. Perform trip test as per Section 4.0
8.19 Under/Over
Voltage
Capbank
Protection
Scheme
The following test shall be performed to commission the Under/Overvoltage
Capbank Protection scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. Verify UV element blocking with CB status during energization.
c.
8.20 Point of
Wave Switching
Control Scheme
Perform trip test as per Section 4.0
The following test shall be performed to commission the Point of Wave switching
control scheme:
a. Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
b. Verify CB closing circuit is wired as per intended
c.
Perform CB operational test as per Section 4.0. The performance of CB
opening (reactor bay) and closing (capacitor bay) shall be monitored and
verified using test set.
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8.21 Voltage
Selection
Scheme
The following test shall be performed to commission the Voltage Selection
scheme:
a. Secondary voltage injection as per Appendix M to test all voltage circuits
b. Where bus-section and bus coupler bays are available, all possible
configurations shall be tested.
c.
For Digital Substation design, the VSS scheme shall include:
•
Verify the busbar CVT is correctly wired up to the corresponding buswire
•
Verify the correct running bus voltage reached to the Bay Controller and
CBM (only applicable for OHL with AR Scheme) with the correct Q1 and
Q2 assignment.
•
Verify the incoming voltage reached to the Bay Controller and CBM (only
applicable for OHL with AR Scheme).
d. For Conventional Substation with Busbar CVT, the VSS scheme shall include:
• Verify the busbar CVT is correctly wired up to the corresponding buswire
•
Verify the correct running bus voltage reached to the bay (only applicable
for OHL with AR Scheme) with the correct Q1 and Q2 assignment.
•
Verify the incoming voltage reached to the bay (only applicable for OHL
with AR Scheme).
e. For Substation without Busbar CVT, the VSS scheme shall include verification
of priority scheme for each bay:
For example in a double busbar configuration as illustrated in Figure Q3 the
priority scheme shall be tested for all possible operating conditions e.g.:
/.
/
2
.
*04
2
1
No
Feeder under test
*
3
) !'
1
Test
condition
Result
on
secondary
voltage selection bus
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1
Feeder 4 on R Bus
2
Feeder 4 on R Bus
3
Feeder 4 on R Bus.
Feeder 3 on M2
4
Feeder 1 on M1.
Feeder 3 on M2.
Feeder 2 and 4 on R
bus
Feeder 1, 2 and 4 on
R bus. Feeder 3 on
M2
5
f.
Feeder 1, 2, 3
CB open. B/C
and
B/S
closed.
Feeder 1, 2, 3
CB open. B/C
open and B/S
closed.
Feeder 1, 2
and B/C CB
open and B/S
closed
All CB closed
All CB closed
Voltage for bus M1, M2 and
R shall be from feeder 4.
No voltage on M1 and M2
bus. Voltage for R shall be
feeder 4.
Voltage for M1, M2 from
feeder 3 and voltage for R
from feeder 4
Voltage for M1, M2 and R
bus shall be from feeder 1.
Voltage for M1, M2 and R
bus shall be from feeder 3.
Any AC interlock, negative DC or positive DC priority scheme provided shall
be tested.
g. CVT MCB trip and busbar CVT Open blocking signals from the priority bay
shall be tested for all bays.
h. All necessary tests to prove that any component or relay failure in the scheme
do not cause any of the CVT’s to be back energized shall be performed.
i. The performance of the voltage selection scheme shall also be tested during
live transfer.
j. All possible conditions tested shall be clearly mentioned in the test report.
k. Test for any alarm provided for the scheme.
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8.22 Live
Transfer
Scheme
The following test shall be performed to commission the Live Transfer scheme:
For Digital substation, Live Transfer scheme implementation is in Bay Controller
Unit.
a.
Test form as required in Appendix A shall be prepared.
b. Test live transfer interlock scheme for each bay for all the following conditions:
Live transfer from Main to Reserve Bus
Live Transfer from Reserve to Main
Live Transfer with Bus-Coupler and/or Bus-Section open.
c. Bus-coupler and Bus-section trip blocking shall be checked during live transfer
for each bay. Verify trip blocking applicable to all protection except busbar
protection.
d. Opening of isolator during live transfer is permitted only when the other isolator
is fully closed. This test shall be carried out for all isolators.
e. All possible conditions tested shall be clearly mentioned in the test report.
f.
Test for any alarm provided for the scheme e.g. live transfer in progress.
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8.23
Switchgear
Operation &
Interlocking
Scheme
The following test shall be performed to commission the Interlock scheme:
For Digital substation, Switchgear Operation and Interlocking scheme
implementation is in Bay Controller. Local interlock verification in this section is still
required for Digital Substation.
a.
Section 3.0 shall be strictly followed to perform the operation and interlock
tests.
b. Interlock test shall only be performed after:
i.
ii.
c.
Alignment test of all isolators completed
Isolator auxiliary contact timing test completed
Interlocking condition from busbar isolator, line isolator and earthing switch
shall only be given when the isolator’s primary arm is fully open or close.
d. Position indication of switchgear at remote and supervisory shall only be given
when the isolator’s primary arm is fully open or fully closed.
e. Verify Reconnection Inhibit for Capacitor circuit breaker. Confirm CB is not
allowed to close immediately after it was detected open until timer elapsed
f.
Interlock test for all switchgears shall be tested from the following positions:
Local operation interlock
Remote operation interlock
Supervisory operation interlock
g. Both mechanical and electrical interlock shall be tested.
h. Verify Earth Switch Interlock.
i.
Test for any alarm provided for the scheme.
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8.24 Carrier
/Intertrip
Scheme
The following test shall be performed to commission the carrier/intertrip scheme:
a. All signals whichever available shall be tested and shall include but not be
limited to the following:
1
1
1
1
c.
Distance protection Main 1 Carrier Send,
Distance protection Main 2 Carrier Send,
Distance protection Main 1 Carrier Receive,
Distance protection Main 2 Carrier Receive,
Intertrip send (Eg: CBF, Stub, SF6)
Intertrip receive (Eg: CBF, Stub, SF6)
CBF initiation to remote end (where applicable, usually for Stub
Protection and End Zone Fault in 1HCB)
The following test shall be performed on all above signals:
1
1
1
1
Check all the Send signals reach the remote end relays or CBM (Digital
Substation) with correct indication.
Check all the Receive signals from remote end reach the local relays or
CBM (Digital Substation) with correct indication at the local end.
Record fascia operation for Send and Receive
Record relay operation for Send and Receive e.g. flag relays, CBM
Timing test for signal transmission delay, for all available signals.
Reset time of the receive signal for at least one signal.
Minimum signal window timing (e.g. less than 2.5 ms) of at least one
signal to simulate noise shall be tested. This is to avoid any
transient/spurious signal being transmitted.
d. All general alarms from communication equipment and 48V DC system.
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IOIED consist of the following functions:
8.25 IOIED
(Transformer
Management,
Station IOIED)
Scheme
•
•
•
Tripping Function (Transformer IOIED)
Busbar Measurements (Station IOIED)
Hardwiring Input to digital signals
a. Check DC system is wired as per design.
b. All possible conditions tested shall be clearly mentioned in the test report.
c.
Verify all required signals (measurement, alarm, indications, status, etc.) from
the IOIED are reported to HMI, EGW and SGW
Hardwiring Input to Digital Signals Function
a. Verify all the hardwired signal from the source end is reported to the HMI,
EGW and SGW.
Tripping Function (applicable for Transformer Management IOIED)
a. Perform Trip Test as per Section 4.0. Simulate transformer guard operation by
initiating from the source ends. Shorting of contacts is only allowed at the
source end when the actual operation cannot be simulated
Busbar Measurements Function (applicable for Station IOIED)
a. Perform measurement accuracy checks for the complete range.
b. Measurement parameters shall include all the required parameter as per Grid
Substation Signaling Requirements
c. Verify information consistency among IOIED, HMI, SCADA and EGW.
9.0 Integrated
Protection and
Control
Scheme
Protection and Control Scheme shall be tested and verified upon completion of
secondary injection as per Appendix I, and can be done together or before
Primary injection test for VT and CT as per Appendix L or M, stability test as per
Appendix O whenever required.
Test form as required in Appendix A shall be prepared for all the related tests.
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9.1 Integrated
Line Protection
Scheme
Integrated Line Protection consist of the following functions:
•
•
•
Current Differential Protection
Backup Distance Protection
Thermal Overload
Check DC system is wired as per design.
0
All tests shall be carried out using dummy breaker.
All possible conditions tested shall be clearly mentioned in the test report.
(
Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation
Current Differential Protection
The following test shall be performed to commission the differential protection
scheme:
a. AR (applicable for line application) and CBM initiation test
i. All phase to phase fault
ii. All phase to ground fault
iii. Three phase fault
b. Lockout Intertrip test to verify lock out operation and blocking of auto reclose
scheme at remote end when local end close onto fault via internal Line
Differential communication
c.
End to end communication test (single end injection) to verify intertripping
function and measurement available at remote end. For 3-terminal
application, this test shall be carried out at all ends, e.g A to B, A to C and B
to C.
d. Perform trip test as per Section 4.0
Distance Protection
The following test shall be performed to commission the distance protection
scheme:
a. CBM initiation test.
i. All phase to phase fault
ii. All phase to ground fault
iii. Three phase fault
b. Perform trip test as per Section 4.0
Thermal Overload
The following test shall be performed to commission the thermal overload
protection scheme:
a. Perform trip test as per Section 4.0 to validate there is no tripping circuit wired
as per design.
9.2 Integrated
Distance with
Thermal
Overload
Protection
Integrated Backup Distance with Thermal Overload consist of the following
functions:
•
•
Backup Distance Protection
Thermal Overload
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Scheme
Check DC system is wired as per design.
All tests shall be carried out using dummy breaker.
2
All possible conditions tested shall be clearly mentioned in the test report.
3
Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation
Distance Protection
The following test shall be performed to commission the distance protection
scheme:
a. CBM/CBF initiation test.
i. All phase to phase fault
ii. All phase to ground fault
iii. Three phase fault
b. Perform trip test as per Section 4.0
Thermal Overload
The following test shall be performed to commission the thermal overload
protection scheme:
a. Perform trip test as per Section 4.0 to validate there is no tripping circuit wired
as per design.
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9.3 Circuit
Breaker
Management
Scheme
Circuit Breaker Management (CBM) consist of the following functions:
•
•
•
•
•
Circuit Breaker Failure
Auto-Reclose and Synchronization (applicable for Overhead Line
application)
Remote End Intertrip (applicable for Overhead Line application)
Pole Discrepency (applicable for 275kV bays application)
Overcurrent (Applicable for Transformer and Capacitor Banks
application)
a. Check DC system is wired as per design.
b.
All tests shall be carried out using dummy breaker.
c.
All possible conditions tested shall be clearly mentioned in the test report.
d.
Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
Circuit Breaker Failure Function
The following test shall be performed to commission the Circuit Breaker Failure
protection scheme:
a. CBF initiation shall be performed with all relays which initiating CBF e.g.
Current Differential, and being set with the final settings.
b. CB/Isolator status input check from source end to confirm correct wiring for
feeder (NO and NC Contacts). Simulate invalid status and verify alarm is sent
after time delay
c.
Simulate isolator bridging condition from source end and verify alarm is sent
after time delay
d. Simulate AR in 3 Pole position and simulate a single phase fault condition.
Verify CBF initiation are resulted in all 3 phases.
e. Simulate AR failed and simulate a single phase fault condition. Verify CBF
initiation are resulted in all 3 phases.
f.
Perform Stage 2 trip test to verify remote end and correct busbar trip
accordingly. This test is to validate relay internal logic and the dedicated CBF
bus wiring scheme.
g. Perform trip test as per section 4.0.
Auto-Reclose Function
a. Any blocking signal to the auto-reclose scheme from main protection shall be
tested by simulating the signal at the source point of the signal.
b. Auto-reclose test shall be performed with all relays e.g. Current Differential,
and being set with the final settings.
c. During the auto-reclose simulation test, the synchronizing condition shall be
achieved by injection of voltage to the CBM relay.
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d. Where main and duplicate protection is used, the whole test shall be
repeated for both protections.
e. During all auto-reclose tests, the following signals shall be monitored and
recorded.
Auto-reclose initiate GOOSE signal from the main protection relay
Block auto-reclose GOOSE signal from the main protection relay
Alarm initiated at HMI, SGW, and EGW
Alarm initiated at fascia
All trip and closing signals
All indication at main protection relay and CBM relay
1
1
1
f.
Auto-reclose test for selected faults shall be performed under the following
conditions for all combination of phase to ground fault, phase to phase fault
or three phase faults accordingly
Auto reclose switch OFF
Auto reclose switch ON – DAR only with sync OK
Auto reclose switch ON – DAR only with sync fail
Auto reclose switch ON – SPAR & DAR (evolving faults) with sync OK
Auto reclose switch ON – SPAR & DAR (evolving faults) with sync fail
Auto reclose switch ON – SPAR & DAR (evolving faults) with sync OK
and with external A/R blocking signal
Repeat i-vi with Auto reclose switch selection to 3 and 1+3 (applicable
for 275kV and above)
1
1
1
1
g. Test the A/R scheme is not initiated if the CB is initially open.
h. Test the A/R scheme with CB closing circuit isolated.
i.
Test the “Sync. Fail timer scheme”.
j.
During the auto-reclose test, timing of the following signals shall be monitored
and documented for selected faults:
Measure length of A/R close pulse to the CB closing coil
Measure reclaim time
Measure SPAR dead time
Measure DAR dead time
Measure sync fail timer
1
1
k. Upon successful completion of all above tests, tests as per the Table below
shall be repeated with the actual CB and disturbance recorder connected.
Main Protection
No Fault Injected
1
R-N
2
B-N
3
4
5
R-N followed by B-N
(evolving fault)
R-Y
Y-B
6
7
B-R
R-N
8
B-N
Scheme condition to be tested
Successful single pole A/R (SPAR)
Successful SPAR followed by second
fault in 1 sec of reclaim time
R-N fault followed by evolving fault on YN fault at 650 ms
Successful delay A/R (DAR)
Successful DAR followed by second fault
in 20th sec of reclaim time
SOTF
φ-N, fault immediately after Manual Close
Of CB
φ-N, fault with CB initially open
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9
l.
10
R-N followed by R-N
immediately upon autoreclosing (TOR)
Y-N
11
B-N
12
R-N
TOR (Expected local and remote end
lockout. Remote end Auto-reclose will be
interrupted)
Auto Reclose switched to OFF resulting in
three-pole tripping with lockout operation.
This is to verify external AR bridging
circuit.
Auto Reclose fail resulting in three-pole
tripping without lockout operation and trip
counter operate accordingly. This is to
verify external AR bridging circuit.
Auto Reclose switched to three Pole
resulting in three-pole tripping without
lockout operation and trip counter operate
accordingly. This is to verify external AR
bridging circuit.
Confirm any backup protection not initiate Auto Reclose
m. For 1HCB system, all tests, which are applicable, shall be carried out
including but not limited to:
• Trip on Reclose (TOR) (TOR from bus circuit breaker shall interrupt
operation of center circuit breaker auto-reclosing)
• Priority release scheme to be tested but not limited as per the table below
No
1
Fault
Injected
R-N
Bus Auto
Reclose
1+3
Center Auto
Reclose
1+3
2
Y-B
1+3
1+3
3
RYB
1+3
1+3
4
R-N
OFF
1+3
5
Y-B
OFF
1+3
6
Y-N
1+3
1+3
7
B-N
1+3
1+3
Scheme condition to be
tested
Single phase to ground
fault (SPAR). Expected
dead time difference of 1
sec between bus and
center CB.
Phase-to-phase
fault
(DAR). Expected dead
time difference of 1 sec
between bus and center
CB.
Three-phase fault. No
AR.
Center CB Auto-Reclose
on
SPAR.
Expected
Center CB dead time as
per
setting
without
extension.
Center CB Auto-Reclose
on
DAR.
Expected
Center CB dead time as
per
setting
without
extension.
Bus
CB
in
open
condition. Center CB
Auto-Reclose on SPAR.
Expected Center CB
dead time as per setting
without extension.
Simulate Bus CB fail to
close. Expected dead
time difference of 1 sec
between bus and center
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CB.
At least the following combinations shall be tested
• Each CB individually using dummy breaker
• Both CB’s simultaneously using actual breaker
Synchronization and Voltage Check Function
The following test shall be performed to commission the synchronizing scheme:
a. The following conditions of CB closing shall be tested:
1
Live Line - Live Bus (Synchronized closing)
Live Line – Dead Bus
Dead Line – Live Bus
Dead Line – Dead Bus
b. CVT MCB trip (incoming and running voltage) and Busbar CVT isolator open
(running voltage) blocking signal shall be tested for blocking the voltage
check scheme.
c.
Synchronizing scheme shall also be tested for any CVT MCB trip/Busbar
CVT isolator open condition (expected synchronization permitted when
simulating Live Line Live Bus).
Pole Discrepancy Function
The following test shall be performed to commission the PD scheme:
a. Simulate CB single pole, 2 pole and 3 pole opening and verify PD operation
b. Timing Test and CB Auxiliary contact (NO / NC) verification
c.
Protection trip test as per section 4.0
Intertrip Function (External initiation)
The following test shall be performed to commission the intertrip scheme:
a.
All signals whichever available shall be tested:
Intertrip send (Eg: CBF, Stub, SF6)
Intertrip receive (Eg: CBF, Stub, SF6)
CBF initiation to remote end (where applicable, usually for Stub
Protection and End Zone Fault in 1HCB)
e. The following test shall be performed on all above signals:
1
1
1
1
Check all the Send signals reach the remote end CBM with correct
indication.
Check all the Receive signals from remote end reach the local relays
or CBM with correct indication at the local end.
Record fascia operation for Send and Receive
Record relay operation for Send and Receive e.g. flag relays, CBM
Timing test for signal transmission delay, for all available signals.
Reset time of the receive signal for at least one signal.
Minimum signal window timing (e.g. less than 2.5 ms) of at least one
signal to simulate noise shall be tested. This is to avoid any
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transient/spurious signal being transmitted.
f. All general alarms from communication equipment and 48V DC system
Overcurrent Function
The following test shall be performed to commission the Overcurrent and Standby
protection scheme:
a. Perform protection trip test as per section 4.
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9.4 Bay
Controller
Scheme
Bay Controller (BC) consist of the following functions:
•
•
•
•
•
•
•
Manual Synchronization and Voltage Check (where applicable)
Switchgear Operation and Interlock (Supervisory, Station, and Bay
Levels)
Undervoltage Earth Switch Interlock
Live Transfer
Bay Measurements
Hardwiring Input to digital signals (MMS, GOOSE)
Trip Counter
a. Check DC system is wired as per design.
b. All tests shall be carried out using dummy breaker.
c.
All possible conditions tested shall be clearly mentioned in the test report.
d. Verify all required signals (measurement, alarm, indications, status, etc) from
the Bay Controller are reported to HMI, EGW and SGW
Manual Synchronizing and Voltage Check Function
The following test shall be performed to commission the synchronising scheme:
a.
Secondary voltage injection as per Appendix I to test all voltage circuits.
b. Secondary injection as per Appendix I on the synchroscope (275kV and
above)
c.
Verify Order Run function such that only one bay can be synchronized at a
time.
d.
Control Hierarchy facilities (Control Authority Selector, bay selector and local
selector switches) shall be tested
e. Synchronized closing of CB shall be tested from Supervisory, Station and Bay
levels. The control priority shall be as follows (from highest to lowest):
i.
ii.
iii.
iv.
f.
Local (switchyard)
Bay (Bay Controller)
Station (HMI)
Supervisory (Control Center)
For Supervisory control, the test shall be carried out by initiating control from
the Control Center after communications from the Control Center have been
established via wired SGW.
g. The following conditions of CB closing shall be tested:
Live Line - Live Bus (Synchronized closing)
Live Line – Dead Bus (Voltage checked closing)
Dead Line – Live Bus (Voltage checked closing)
Dead Line – Dead Bus (Voltage checked closing)
1
h. CVT MCB trip (incoming and running voltage) and Busbar CVT isolator open
(running voltage) blocking signals shall be tested for blocking the voltage
check function. The input shall be simulated at all source ends (VT MCB at
MK, VT MCB at VT box etc)
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i.
All necessary tests to prove that any component or relay failure in the scheme
shall not cause any of the CVT’s to be back energized shall be performed.
j.
The performance of the synchronizing scheme shall also be tested during live
transfer condition. following conditions:
Switchgear Operation and Interlock (Supervisory, Station, and Bay Levels)
Functions
a. Section 3.0 shall be strictly followed to perform the operation and interlock
tests.
b. Interlock test shall only be performed after:
Alignment test of all isolators completed
Isolator auxiliary contact timing test completed.
c.
Interlocking condition from busbar isolator, line isolator and earthing switch
shall only be given when the isolator’s primary arm is fully open or close.
d. Position indication of switchgear at remote and supervisory shall only be
given when the isolator’s primary arm is fully open or fully closed.
e. Interlock test for all switchgears shall be tested from the following positions:
Bay operation interlock
Station operation interlock
Supervisory operation interlock
f.
Verify Order Running function which allow control permission one bay at one
time.
g. Verify emergency CB opening is only allowed when Bay Controller fail.
h. Verify Reconnection Inhibit for Capacitor circuit breaker. Confirm CB is not
allowed to close immediately after it was detected open until timer elapsed.
i.
During bay operation interlock check, verify interlock indication light up only
when interlock check has been fulfilled.
Undervoltage Earth Switch Interlock
The following test shall be performed to commission the Undervoltage Earth
Switch Interlock scheme:
Test earth switch interlock scheme to allow or block the earth switch
operation
during local control (switchyard)
Live Transfer Function
The following test shall be performed to commission the Live Transfer scheme:
a. Test live transfer interlock scheme for each bay for all the following
conditions:
Live transfer from Main to Reserve Bus
Live Transfer from Reserve to Main
Live Transfer with Bus-Coupler and/or Bus-Section open.
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b. Bus-coupler and Bus-section trip blocking shall be checked during live
transfer for each bay. Verify trip blocking applicable to all protection except
busbar protection.
c.
Opening of isolator during live transfer is permitted only when the other
isolator is fully closed. This test shall be carried out for all isolators.
Bay Measurements Function
The following secondary injection tests shall be performed:
a.
The measurement accuracy check for the complete range.
b.
Communication test (e.g Modbus) with other devices (e.g. HMI/SGW/EGW)
c.
Measurement parameters shall include all the required signals as per Grid
Substation Signalling Requirements.
d.
Verify information consistency among Bay Controller, HMI, SCADA and
EGW.
Hardwiring Input to Digital Signals (MMS, GOOSE) Function
a. Verify all the hardwired signal from the source end is reported to the HMI,
EGW and SGW via the Bay Controller.
Trip Counter Function
a. Verify that all tripping from protection relays and master trip relay will operate
the trip counter.
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9.5 Overload
and
Overcurrent
Capbank
Scheme
This application consists of the following functions:
•
•
Overload Capbank
Overcurrent Capbank
a. Check DC system is wired as per design.
b. All possible conditions tested shall be clearly mentioned in the test report.
c.
Verify all required signals (measurement, alarm, indications, status, etc.) from
the IOIED are reported to HMI, EGW and SGW
Overload Capbank
a. Perform Trip Test as per Section 4.0.
Overcurrent Capbank
a. Perform Trip Test as per Section 4.0.
Busbar Measurements Function (applicable for Station IOIED)
The following test shall be performed to commission the Overcurrent scheme:
a. Perform protection trip test as per section 4.
The following test shall be performed to commission the Under/Overvoltage
Capbank Protection scheme:
k.
Secondary injection as per Appendix I to test alarm (fascia, HMI, EGW),
SCADA and counter operation.
l.
Verify UV element blocking with CB status during energization.
m. Perform trip test as per Section 4.0
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9.6
Undervotlage
and
Overvoltage
Capbank
Scheme
This application consists of the following functions:
•
•
Undervoltage Capbank
Overvoltage Capbank
a. Check DC system is wired as per design.
b. All possible conditions tested shall be clearly mentioned in the test report.
c.
Verify all required signals (measurement, alarm, indications, status, etc.) from
the IOIED are reported to HMI, EGW and SGW
Undervoltage Capbank
a. Verify UV element blocking with CB status during energization.
b. Perform Trip Test as per Section 4.0.
Overvoltage Capbank
a. Perform Trip Test as per Section 4.0.
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SAT Appendix O: SAT Stability Test of Unit/Differential Protection
1.0
2.0
3.0
4.0
5.0
6.0
Purpose ..................................................................................................................................... 1
Requirement prior to Stability Test............................................................................................ 1
Testing Conditions and Restrictions ......................................................................................... 2
Stability Tests for Unit Protection .............................................................................................. 3
Stability Tests for Differential/ Comparison Protection ............................................................. 4
Stability Tests for High Impedance Busbar Protection ............................................................. 6
Stability test using synchronized secondary injection method…………………………………...7
1.0
Purpose
To provide SAT requirements in carrying out stability tests for all types of
unit/differential protection e.g.:
• High Impedance protection for:
Transformer High Impedance
Transformer HV REF
Transformer LV REF
Busbar protection
T-zone protection
•
•
2.0
Requirement
prior to
Stability Test
Differential protection for:
Transformer
Generator
Line
Cable
Low Impedance busbar protection
The pre-requisites for carrying out stability tests include:
a. Drawing and design verification of the particular unit/differential protection.
b. CT ratio selection of the unit/differential protection has been finalized. CT
loop resistance measurement shall be completed and clearly documented.
c.
Ratio and vector group of the Interposing CT in the unit/differential protection
has been finalized.
d. All final settings of the unit/differential protection have been calculated,
implemented and documented including stabilizing resistor if any.
e. Test procedure as per Appendix B shall be available.
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2.0
Requirement
prior to
Stability Test
(Cont. 1)
f.
Test form as required in Appendix A shall be prepared with the following
additional information:
CT Ratios and knee point voltage of all CT’s in the unit/differential
protection.
ICT ratio and vector group for all ICT’s in the unit/differential protection if
any.
Relay settings
For transformer differential protection, the following additional information
is to be included:
Transformer MVA
Transformer Ratio
Transformer Vector Group
Fault simulated e.g. R-N, Y-N, in-zone, out-zone etc.
Primary current values – at least 10% of rated CT ratio
Secondary current readings:
At CT
After ICT’s
Relay operating current
3.0
Testing
Conditions
and
Restrictions
a. All stability tests of the plant shall be carried out as the last SAT activity prior
to the plant being commissioned. This may include stability tests for busbar
protection, transformer differential protection and transformer high impedance
protection.
b. Any modification on a unit/differential protection scheme that has been
tested shall subject that particular scheme to a complete retest.
c.
When stability tests are being carried out in a live substation all necessary
isolation and precautions shall be documented in the testing procedure.
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4.0
Stability
Tests for Unit
Protection
#
%
$
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a. Based on Figure R1 stability tests shall be carried out for all unit protection
e.g. transformer HV REF, LV REF etc. as follows:
Tests shall be carried out for in-zone fault at point XX and out-zone
fault at point YY.
The test shall be performed for all phases, R-N, Y-N and B-N.
During the test, record the following readings:
Primary currents at both points A and B.
CT secondary currents at the MK (points C and D)
Relay operating current (point E)
Voltage measurement at relay (point F) for high impedance
protection.
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b. For unit protection using three CT’s as illustrated in Figure R2, e.g. T-zone
protection of 1½ breaker system, stability test shall be proven between points
A & C and points A & B or points B & C.
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5.0
Stability
Tests for
Differential/
Comparison
Protection
% !
% !
''
(
a.
)
! "
''
Based on Figure R3, stability tests shall be carried out for all differential/
comparison protection e.g. transformer differential protection, line/cable
differential protection etc, as follows:
Tests shall be carried out for
In-zone three-phase fault at point XX.
In-zone single phase fault at point XX (If and when possible for one
phase only)
Out-zone three phase fault at point YY.
Out-zone single phase fault at point YY (If and when possible for one
phase only)
During the test, record the following readings:
Primary currents of all phases at both points A and B.
CT secondary currents of all phases at the MK (points C and D)
Secondary current after ICT (point E and F) – where possible.
Relay operating current of all phases
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5.0
Stability
Tests for
Differential/
Comparison
Protection
(Cont. 1)
*
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)+
, #
"
''
b.
For unit protection using three CT’s as illustrated in Figure R4 e.g. 3 winding
transformers, stability test shall be proven between points A & C and points A
& B or points B & C.
c.
For cable and line feeder with unit protection complete stability test shall be
performed. Where it is not possible to perform the stability test, can be proven
during on-load tests.
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6.0
Stability
Tests for
High
Impedance
Busbar
Protection
a. Stability tests shall be carried out for both high impedance and low impedance
busbar protection scheme. For low impedance busbar protection scheme,
stability test shall be carried as recommended in the manufacturer’s manual.
b. Fault simulation and measurement points shall be as per the stability test for
unit protection.
c.
Stability test shall be performed both for the check zone and all discriminative
zones.
d. Both in-zone and out-zone fault conditions shall be simulated and tested for all
phase.
e. The following is the stability test example meant for a double busbar
configuration with bus-coupler and bus-section as illustrated in Figure R5
Similar concept shall be used to test other types of busbar configurations.
f.
One feeder shall be selected and maintained as a reference bay. All tests as
listed in the table below shall be carried out to prove the stability.
/
1
0
-&
-
.
&
.
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)
$
$"
*
' $
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7.0
Stability test
using
synchronized
secondary
injection
method
a. The synchronized secondary injection method is applicable when there is no
CT replacement, and requires:
i.
ii.
iii.
iv.
Two units of secondary test set with same capability and
characteristic (one at each ends of the differential scheme)
Synchronized injection (using GPS) - differences in injection time
will cause phase difference which will cause inaccurate /
incorrect results
Secondary injection should be carried out as close as possible to
the secondary terminal of the CT (Marshaling Kiosk) - this will
ensure that all secondary wiring will be part of the stability test
For 3-terminal scheme, the secondary injection should be carried
out from A to B terminal, and then proceed with A to C terminal.
b. The test shall be conducted to low impedance unit protection i.e. OHL/UGC
feeders, interconnectors and transformers differential where necessary.
8.0
Stability test
using
synchronized
primary
injection
method
a. The synchronized primary injection method when there is CT replacement,
and requires:
i.
ii.
iii.
c.
Two units of primary test set with same capability and
characteristic (one at each ends of the differential scheme)
Synchronized primary injection (using GPS) - differences in
injection time will cause phase difference which will cause
inaccurate / incorrect results
For 3-terminal scheme, the primary injection should be carried
out from A to B terminal, and then proceed with A to C terminal.
The test shall be conducted to low impedance unit protection i.e. OHL/UGC
feeders, interconnectors and transformers differential where necessary.
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SAT Appendix P: SAT for Final Inspection and Check
1.0
2.0
3.0
4.0
5.0
6.0
7.0
Purpose ..................................................................................................................................... 1
Requirement.............................................................................................................................. 1
Panel Inspection........................................................................................................................ 1
Setting Check ............................................................................................................................ 2
Primary Equipment & Switchyard Inspection ............................................................................ 2
Building & Civil .......................................................................................................................... 2
Final Operation & Trip Test ....................................................................................................... 2
1.0
Purpose
At the end of the SAT, one day before energizing, the following final inspection
and check shall be carried out :
•
•
•
Panel Inspection
Setting check
Final operation and trip test
2.0
Requirement
a. The final inspection and check shall be carried out by the contractor and
witnessed by TNB. Each check list shall be countersigned by both parties.
3.0
Panel
Inspection
a. All cubicles and panels as shall be subjected for panel inspection e.g.:
CB, isolator control cubicles
Transformer Local control panel, RTCC panel
Protection control and relay panels
b.
The inspection shall be carried out using a proper check list. Each cubicle
shall have a dedicated check list. Panel Inspection shall be documented as
part of the commissioning report.
c.
The following shall be checked for in each panel:
Heater switched on
All MCB’s are switched on.
All terminal block links are closed and tight including spares.
All wires are properly terminated except spare wires.
A proper note (with the purpose, person-in-charge and date) shall be
made available for any:
Terminal block links left open intentionally
Wire open/disconnected intentionally.
MCB left ‘OFF’.
Check that there are no openings e.g. holes, doors not properly closed
and door gaskets.
Cubicle/panel lighting facility shall be functioning.
Panel earthing and component earthing is complete.
Check cubicle/panel for cleanliness.
All temporary shorting/looping removed.
d. Panels/cubicles shall be locked upon completion of the above inspection.
!"
# #
4.0
Setting
Check
All protection relay settings shall be re-checked with the documented final
approved/endorsed settings.
All other settings e.g. SF6 pressure gauge, winding temperature trip etc. shall
also be checked.
Confirm date and time of relays etc are set correctly.
Clear all test records/events from relays and recorder
a. Check all valves on transformers are in operational position.
5.0
Primary
Equipment &
Switchyard
Inspection
b. All temporary earthing in switchyard removed.
c.
All fuses are in and MCB are ON.
a. Check fire-fighting system is on
6.0
Building &
Civil
b. Check A/C and all electrical and mechanical system.
c.
Check Switchyard lighting
a. Test operation of all switchgear from substation control room.
7.0
Final
Operation &
Trip Test
b. Perform one trip test from each protection relay i.e. distance, overcurrent,
differential protection etc, by secondary injection. All circuit breakers shall be
subjected to this trip test.
#
!"
# #
SAT Appendix Q: SAT for Secondary Live Maintenance
1.0
2.0
3.0
4.0
Purpose ..................................................................................................................................... 1
Requirement Prior to Live Maintenance Verification ................................................................. 1
Main Line Intergrated Current Differential Protection ............................................................... 1
Circuit Breaker Management .................................................................................................... 2
1.0
Purpose
To perform secondary injection test for protection relays in live condition to
validate Live maintenance features as intended design and certified the panel as
“Live Maintenance Ready”.
2.0
Requirement
Prior to Live
Maintenance
Verification
This test should only be started after the following activities or conditions have
been successfully verified:
a. To check local/remote weather in good condition.
b. Ensure all relays are in good condition. Ensure no relay indications are in
operation.
c.
Ensure all tools (meters and shorting leads) are in good condition
d. Ensure all test plug connection are as per drawing
e. To check loading for the tested OHL/UGC bay at both ends and the parallel
bay. Ensure that the load current is no less than 10% of the line rating. Also
ensure the bay under test and its parallel bay both carry less than 50% of its
total capacity to ensure N-1 contingency
f.
Ensure that there is no direct DC Earth Fault. Live Maintenance can proceed
on high resistance DC Earth Fault (80% voltage) condition.
g. Inform NLDC on Live Maintenance Works and Head of Zone after approval
by NLDC.
h. Label the relays being tested “LIVE MAINTENANCE TESTING IN
PROGRESS”
i.
Refer to Testing Checklist as annexed in this document:
a.
b.
3.0
Main
Line
Integrated
Current
Differential
Protection
SAT Live Maintenance Certification (Phase 2) Testing Checklist F11L
M1/M2 Line Integrated Current Differential Protection for 275/500kV
OHL/UGC
SAT Live Maintenance Certification (Phase 2) Testing Checklist F52CBM
Circuit Breaker Failure Protection for 275/500kV OHL/UGC
The following procedure shall be taken in the order as per below. The following
example is performed on the Main 1 Line Integrated Current Differential
Protection:
a. Read and record Ibias and Idiff, voltage and power direction for all phase at the
F11L(M1) relay at both ends. Expected value of all current input should be
identical at both ends and Idiff must be zero. If measurements are not as per
expected value, further investigation is to be carried out.
b. Remove/pull out Group Isolation Link for F11L(M1) at both stations and
! "#
$ $
validate the action by voltage measurement. Ensure measured voltage is
zero at the following output contacts:
i.
ii.
iii.
iv.
c.
Trip Coil 1 (Bus CB and Center CB for 1HCB)
Master Trip 1 & 2 (Bus CB and Center CB for 1HCB)
Start CBF – R, Y, B, 3-ph (Bus CB and Center CB for 1HCB)
Block AR (Bus CB and Center CB for 1HCB)
Apply second trip isolation, shorting CT and Opening VT circuit by inserting
test plug for F11L(M1) at both ends. Relay may operate and trigger indication
at fascia at this point. Ensure there are no tripping to the Circuit Breaker.
d. Check and verify from F11L(M1) HMI that there are no current input, voltage,
Ibias and Idiff at both ends. This verifies the relay is already isolated from the
CT and VT circuit via the test plug.
e. Remove/pull out CT shorting and VT Group Isolation Link for F11L(M1).
Ensure that the secondary current and voltage at the F11L(M1) test terminal
block is zero.
f.
Perform both 87L and 21Z trip test function via the test plug. All tests shall
use wet contact from the test plug only and the positive and negative supply
can be taken directly from the test plug. Confirm and verify that there are no
tripping of the Circuit Breaker, Master Trip Relay operation, and initiation to
start the CBF function.
g. Reset all fascia and relay indications.
h. Normalizing the system by first insert/put in CT/VT shorting and CT Group
Isolation Link for F11L(M1) at both ends.
i.
Measure and record the secondary current and voltage at the F11L(M1) test
terminal block. Ensure that the current and voltage input from the CT and VT
reaches up to the test terminal block at both ends.
j.
Remove the test plug for F11L(M1) at both ends. Relay may operate and
trigger indication at fascia at this point. Ensure there are no tripping to the
Circuit Breaker.
k.
Check and verify from the F11L(M1) HMI the current input, voltage, Ibias and
Idiff at both ends. Ensure that the current and voltage input from the CT and
VT reaches up to the F11L(M1) relay terminal at both ends. Ensure Idiff is zero
and the relay is not in operation.
l.
Insert/put in Group Isolation Link for F11L(M1) at both stations. Ensure
measured voltage is negative at the following output contacts.
i.
ii.
iii.
iv.
4.0
Circuit
Breaker
Management
Trip Coil 1 (Bus CB and Center CB for 1HCB)
Master Trip 1 & 2 (Bus CB and Center CB for 1HCB)
Start CBF – R, Y, B, 3-ph (Bus CB and Center CB for 1HCB)
Block AR (Bus CB and Center CB for 1HCB)
The following procedure shall be taken in the order as per below:
a. Read and record the current and voltage measurement for all phase at the
F50CBM relay.
$
! "#
$ $
b. Remove/pull out Group Isolation Link for F50CBM. Ensure measured voltage
is zero after isolation:
i.
ii.
iii.
iv.
v.
c.
Master Trip 1 & 2 (Bus CB and Center CB for 1HCB)
CBF Stage 2 to Busbar (Bus CB for 1HCB)
CBF Stage 2 to Center CB (Bus CB for 1HCB)
CBF Stage 2 to Bus CB (Center CB for 1HCB)
Intertrip to remote end (Both feeders for Center CB in 1HCB)
Perform second trip isolation and shorting CT and Opening VT circuit by
inserting test plug for F50BCM. Relay may operate and trigger indication at
fascia at this point. Ensure there are no tripping to the Circuit Breaker.
d. Check and verify from F50BCM HMI that there are no current and voltage
input to the relay. This verifies the relay is already isolated from the CT and
VT circuit via the test plug. Measure and record the current circuit the Digital
Fault Recorder and relay HMI.
e. Apply second CT shorting and VT opening by removing/pulling out CT
shorting and VT Group Isolation Link for F50CBM. Ensure that the secondary
current and voltage at the F50CBM test terminal block is zero. Measure and
record the secondary current and voltage at the F50CBM relay test terminal
block.
f.
Perform the following functions via the test plug:
i.
ii.
iii.
iv.
v.
CBF Stage 1
CBF Stage 2
Pole Discordance
Intertrip Receive and Send
Auto-Reclose Start and Blocking
All tests shall use wet contact from the test plug only and the positive and
negative supply can be taken directly from the test plug. Confirm and verify
that there are no tripping of the Circuit Breaker, Master Trip Relay operation,
and initiation to start the CBF function.
g. Reset all fascia and relay indications.
h. Insert/put in CT shorting and CT Group Isolation Link for F50CBM.
i.
Measure and record the secondary current and voltage at the F50CBM test
terminal block. Ensure that the current and voltage input from the CT and VT
reaches up to the test terminal block.
j.
Remove the test plug for F50CBM. Relay may operate and trigger indication
at fascia at this point. Ensure there are no tripping to the Circuit Breaker.
k.
Check and verify from the F50CBM HMI the current and voltage input. Ensure
that the current and voltage input from the CT and VT reaches up to the
F50CBM relay terminal. All current and voltage input at the F50CBM relay is
expected to be the same as the Digital Fault Recorder. Further investigation
is to be carried out if measurement values are not as expected
l.
Insert/put in Group Isolation Link for F50CBM. Ensure measured voltage is
negative at the following output contacts:
i.
ii.
iii.
Master Trip 1 & 2 (Bus CB and Center CB for 1HCB)
CBF Stage 2 to Busbar (Bus CB for 1HCB)
CBF Stage 2 to Center CB (Bus CB for 1HCB)
%
! "#
$ $
iv.
v.
•
5.0
Certification
! "#
CBF Stage 2 to Bus CB (Center CB for 1HCB)
Intertrip to remote end (Both feeders for Center CB in 1HCB)
Test shall be verified and certified by all the relevant parties, namely Tester,
Electrical Service Engineer and TNB representative (PM and GM). Upon
completion, “Live Maintenance Ready” sticker shall be provided to the panel
per said.
$ $
SAT Live Maintenance Certification (Phase 2)
Testing Checklist F11L M1/M2 Line
Integrated Current Differential Protection for
275/500kV OHL/UGC
CONTENTS:
1. WORK OBJECTIVE
2. LOCATION
3. SCOPE OF WORK
3.1
Work Description
3.2
Work Program
4. RISK ANALYSIS
5. DETAILS WORK PROCEDURES (WORK INVOLVE)
5.1
Prerequisite Check (System Condition Check)
5.2
Wiring &Setting Check (F11L(M1)
5.3
Isolation / Scheme Defeat (F11L(M1)
5.4
Testing Work (F11L(M1)
5.5
Normalization & Scheme Restoration
6. CONTIGENCY ACTION PLAN
1. WORK OBJECTIVE
To perform secondary injection test for Main 1 & Main 2 Line Integrated Current
Differential Protection relay in live condition to validate Live maintenance feature
as intended design and certified the panel as “Live maintenance Work
Compliance”,
2. LOCATION
PMU: ……………………………………….
Panel Designation: ………………………
3. SCOPE OF WORK
3.1 Work Description
• To perform operational and timing test secondary injection for Main1
F11L & Main 2 F11L in live condition and apply live maintenance
feature.
• To verify all tripping output and SCADA & annunciator indication in
functional and good condition.
• To certify the panel ready to perform Preventive Live Maintenance
3.2 Work Program
Work Description
Remark
1) Preliminary check at Site/Bay/Panel for verification of CT
circuit, VT circuit, tripping circuit, Test Socket & Isolation
check list
2) Trip isolation and short CT/Open VT circuit at
F11L(M1/M2)
3) Testing F11L(M1/M2) protection relay
4) Normalize trip output and CT/VT circuit at F11L(M1/M2)
4. RISK ANALYSIS
Detail work description, the RISK of each activity and the Mitigation involved
Description
1. Testing Activity
Risk involved
Personnel
a) DC or AC supply
insulation leak may cause
electrical shock.
b) Flashover due to wrong
termination may cause
Mitigation / Minimizing
Risk
Personnel
i) Use proper PPE & tools.
ii) Check insulation
resistance of wiring to
earth.
iii) Do not leave any cut
Description
Risk involved
injury.
Apparatus/Equipment
a. Damage to relays due to
testing
b. Damage of CT due to CT
open Circuit
Mitigation / Minimizing
Risk
wires in the trucking.
Apparatus/Equipment
i) Injection values must not
exceed rated values stated
in the relay manuals.
ii) When handling relay
printed circuit board always
earth body to prevent static
voltage.
iii) Use the correct DC
voltage to energize relay
inputs.
i) Make sure shorting leads
and test plug in good
condition.
ii) Confirm function no. from
relay to terminal block is
correct.
iii) Make current
measurement to confirm
shorting done properly.
System
i) Extra care to be taken to
ensure the correct bay
under-test at both ends is
i) Wrongly implementing
live maintenance procedure identified
ii) Ensure that test plug in
in sequence
good condition
ii)DC earth fault can cause
iii) Ensure the correct
mal operation to the
relays been identified for
existing system.
iii) protection scheme is not testing for both ends.
iv) Ensure correct
fully switched off/defeated.
sequence during isolation
before perform testing with
validation
System
Tripping of live bays.
5.0 DETAILS WORK PROCEDURES (WORK INVOLVE)
5.1 Prerequisite Check (System Condition Check)
Action
To check local/remote weather in good condition
Make sure Protection personal at remote END ready for;
• To remove group isolation link
Make sure all relays in good conditions. Ensure no relay
indication operated
To make sure all required tools in good condition (meters
and test plug)
To make sure all test plug connection as per drawing.
To check loading for tested OHL/UGC bay at both end
and the parallel bays.
Ensure load current not less than 10% of line rating
Note: At any condition, bay under test and parallel bays
shall carry less than 50% load to allow for N-1
contingency
Prerequisite
before testing
Measure DC voltage to check for any DC earth fault
1) If there is direct DC Earth Fault. Live maintenance
shall not be proceeded
2) If the DC Earth Fault was high resistive (80%
voltage), Live Maintenance can be proceeded with
consensus from TNB. Inform to TNB management or
Head Of Unit
Inform NLDC for Live Maintenance
Transfer all bay to Reserve busbar and tested bay at
Main busbar at both stations. Set Bus Separation
zone 2 instantaneous
Remarks
5.2 Isolation / Scheme Defeat 87L(M1)
Objective
Step
1
To confirm
Ibias & Idiff
of 87L
Action
Read & record I bias & I diff measurement, voltage and power
direction all phase at F11L(M1) relay at both end
PMU A:
Phase
I
local
I
remote
I bias
(Amp)
I diff
(Amp)
Voltage
Power
Direction
I
local
I
remote
I bias
(Amp)
I diff
(Amp)
Voltage
Power
Direction
Verification/
Remark
Ensure
measurement at
both station
identical and I diff
expected 0 amp
Red
Yellow
Blue
PMU B:
Phase
Red
Yellow
Blue
Note:
Expected all current value input should be identical at both end
and I diff must be zero. If measurement is not as per
expected value, further investigation to be carried out.
Step
2
To apply
isolate
tripping
F11L(M1)
i- Remove/Pull out Group Isolation Link for F11L(M1) at
both stations.
Note: For 1HCB, remove group isolation link for each CB
Measure output from F11L(M1) at test plug
Description
Expected
Voltage
CB Trip Coil 1 R phs
0
CB Trip Coil 1 Y phs
0
CB Trip Coil 1 B phs
0
Master trip 1 Operated
0
Master trip 2 Operated
0
Start CBF phs. R
0
Start CBF phs. Y
0
Measured
Voltage
Confirm and
verify 0 V dc
voltage at output
contact for
tripping and CBF
initiation at test
plug
PASS/FAILED
Objective
Action
Verification/
Remark
Start CBF phs. B
0
Start CBF 3 phs.
0
Block A//R
0
CB Trip Coil 1 R phs- Q0B
0
CB Trip Coil 1 Y phs -Q0B
0
CB Trip Coil 1 B phs-Q0B
0
Master trip 1 Operated-Q0B
0
Master trip 2 Operated-Q0B
0
Start CBF phs. R -Q0B
0
Start CBF phs. Y -Q0B
0
Start CBF phs. B -Q0B
0
Start CBF 3 phs. -Q0B
0
Block A/R-Q0B
0
Note: -Q0B Center CB for 1HCB
ii- Check and verify input CBM “A/R Inhibit BI” records no
voltage
Measure at CBM relay
Description
Expected
Voltage
Main 1 A/R Inhibit
0V
Main 2 A/R Inhibit
+ 60 V
Measured
Voltage
Confirm and
verify at relay
CBM voltage at
input “A/R Inhibit”
for Main 1 or 2
(whichever under
tested) not
available
PASS/FAILED
Main 1 A/R Inhibit
Note: Only applicable for
1HCB center CB
0V
Main 2 A/R Inhibit
Note: Only applicable for
1HCB center CB
Step
3
To apply
2nd trip
isolation
and short
CT & open
VT circuit
+ 60 V
i- Insert test plug RTXP24 for F11L(M1) at both end
Note: During insert test plug, F11L(M1) relay may operate
and indication at facia will trigger. Expect no tripping to CB as
Group Isolation link has isolated the tripping circuits.
ii- Check and verify from F11L(M1) LCD no current input,
voltage, Ibias and Idiff at both end. This verify F11L(M1)
already isolated from CT & VT circuit by test plug.
Confirm and
verify from
F11L(M1)
HMI/LCD that no
current input,
voltage, Ibias and
Idiff at both ends.
Objective
Action
Verification/
Remark
PASS/FAILED
PMU A:
Phase
I local
I remote
I bias
(Amp)
I diff
(Amp)
Voltage
Local
I local
I remote
I bias
(Amp)
I diff
(Amp)
Voltage
Local
Red
Yellow
Blue
PMU B:
Phase
Red
Yellow
Blue
iii- Reset relay F11L at both ends. Ensure no relay operation.
Insert back group isolation link.
Verify tripping related circuits isolation with test plug insertion by
measuring output from F11L(M1) at relay terminal.
Description
Expected
Voltage
CB Trip Coil 1 R phs
0
CB Trip Coil 1 Y phs
0
CB Trip Coil 1 B phs
0
Master trip 1 Operated
0
Master trip 2 Operated
0
Start CBF phs. R
0
Start CBF phs. Y
0
Start CBF phs. B
0
Start CBF 3 phs.
0
Block A//R
0
CB Trip Coil 1 R phs- Q0B
0
CB Trip Coil 1 Y phs -Q0B
0
CB Trip Coil 1 B phs-Q0B
0
Measured
Voltage
Confirm and
verify no tripping
and no CBF
initiation by
voltage
measurement.
verify 0 V dc
voltage at output
contact for
tripping and CBF
initiation at relay
terminal
PASS/FAILED
Objective
Action
Verification/
Remark
Master trip 1 Operated-Q0B
0
Master trip 2 Operated-Q0B
0
Start CBF phs. R -Q0B
0
Start CBF phs. Y -Q0B
0
Start CBF phs. B -Q0B
0
Start CBF 3 phs. -Q0B
0
Block A/R-Q0B
0
Note: -Q0B Center CB for 1HCB
iii- Check and verify CBM “A/R Inhibit BI” records voltage
Measure at CBM relay
Description
Expected
Voltage
Main 1 A/R Inhibit
+ 60 V
Main 2 A/R Inhibit
+ 60 V
Measured
Voltage
Main 1 A/R Inhibit
Note: Only applicable for
1HCB center CB
+ 60 V
Main 2 A/R Inhibit
Note: Only applicable for
1HCB center CB
+ 60 V
iv- Remove Group trip isolation link again to ensure double trip
isolation implemented
Step
4
To apply
2nd short
CT Circuit
F11L at
terminal
block
Remove or pull out CT Shorting & VT group isolation link for
F11L(M1)
Measure and record secondary current and voltage at terminal
test block relay F11L(M1)
PMU A
Phase
Red
Yellow
Blue
Current (Amp)
Voltage
Confirm and
verify CT/VT
cirucit is shorted
and isolated by
AC Group
Isolaiton link.
Measure no
current and
voltage input,
voltage both end.
PASS/FAILED
Objective
Action
Verification/
Remark
PMU B
Measure and record secondary current and voltage at terminal
test block relay F11L(M1)
Phase
Current (Amp)
Voltage
Red
Yellow
Blue
5.3 Testing Work (F11L(M1)
Objective
Verification/
Remark
Action
Step
5
To verify relay
communication
Record existing communication Setting for Local and remote.
Address
LOCAL
REMOTE
Address for loop back testing
Address
LOCAL
REMOTE
Step
6
To proceed
with functional
F11L testing
Perform 87L trip test function at both ends. Ensure
lockout relay 86E 1/2 not operated, no initiation to CBF
Phase
R-N
Y-N
B-N
R-Y-B
Relay
Operation
86E1/2
Start
CBF
CB
Operation
Confrim and
verify no CB
tripping, 86E
operation and
no CBF
initiation.
PASS/FAILED
Objective
Verification/
Remark
Action
Perform 21Z trip test function
Phase
Relay
Operation
86E1/2
Start
CBF
CB
Operation
Zone 1
R-N
Zone 2
Y-N
Zone 3
B-N
* All testing using wet contact from test plug only and
supply +ve or –ve can be taken directly from RTXP24
87L(M1) test plug
5.4 Normalization & Scheme Restoration (F11L(M1)
Objective
Action
Step
7
Ready for
normalization
Reset all facia and relay operation
! "
Normalize CT
circuit and VT
circuit
Insert or pull-in CT shorting & VT group isolation link for
F11L(M1) at both end
Measure and record secondary current and voltage at terminal
test block relay F11L(M1)
PMU A
Phase
Current (Amp)
Voltage
Verification/
Remark
Confirm and
verify from
CT/VT terminal
F11L(M1)
current and
voltage input
available at
both end
Red
Yellow
PASS/FAILED
Blue
PMU B
Phase
Red
Yellow
Current (Amp)
Voltage
Objective
Action
Verification/
Remark
Blue
! "
To normalize
CT & VT
circuit to relay
F11L(M1)
i- Remove test plug RTXP24 for F11L(M1) at both end
Note: During remove test plug, F11L(M1) relay may operate
and indication at facia will trigger. Ensure no tripping to CB
ii- Check and verify from F11L(M1) LCD current input, voltage,
Ibias available and Idiff at both end 0 amp. This verify
F11L(M1) already connected from CT & VT circuit.
PMU A:
Phase
I local
I remote
I bias
(Amp)
I diff
(Amp)
Voltage
Local
Red
Yellow
Blue
Confirm and
verify no
tripping and no
CBF initiation.
Confirm and
verify from
F11L(M1) LCD
current input,
voltage, Ibias
available and
Idiff 0 A at both
end.
PASS/FAILED
PMU B:
Phase
I local
I remote
I bias
(Amp)
I diff
(Amp)
Voltage
Local
Red
Yellow
Blue
Verify trip isolation from test plug by measure output from
F11L(M1) at test plug
Description
Expected
Voltage
CB Trip Coil 1 R phs
0
CB Trip Coil 1 Y phs
0
CB Trip Coil 1 B phs
0
Master trip 1 Operated
0
Master trip 2 Operated
0
Start CBF phs. R
0
Start CBF phs. Y
0
Start CBF phs. B
0
Measured
Voltage
Confirm and
verify 0 V dc
voltage at
output contact
for tripping and
CBF initiation at
test plug
PASS/FAILED
Objective
Action
Verification/
Remark
Start CBF 3 phs.
0
Block A//R
0
CB Trip Coil 1 R phs- Q0B
0
CB Trip Coil 1 Y phs -Q0B
0
CB Trip Coil 1 B phs-Q0B
0
Master trip 1 Operated-Q0B
0
Master trip 2 Operated-Q0B
0
Start CBF phs. R -Q0B
0
Start CBF phs. Y -Q0B
0
Start CBF phs. B -Q0B
0
Start CBF 3 phs. -Q0B
0
Block A/R-Q0B
0
Note: -Q0B Center CB for 1HCB
Step
10
To normalize
tripping
output
i- Insert Group Isolation Link for F11L(M1) at both stations.
Note: Insert each group isolation link for respective CB and
measured output contact at terminal relay.
Description
Expected
Voltage
CB Trip Coil 1 R phs
-60 V
CB Trip Coil 1 Y phs
-60 V
CB Trip Coil 1 B phs
-60 V
Master trip 1 Operated
-60 V
Master trip 2 Operated
-60 V
Start CBF phs. R
-60 V
Start CBF phs. Y
-60 V
Start CBF phs. B
-60 V
Start CBF 3 phs.
-60 V
Block A/R
-60 V
CB Trip Coil 1 R phs- Q0B
-60 V
Measured
Voltage
Confirm and
verify –ve dc
voltage at
output contact
for tripping and
CBF initiation at
terminal relay
PASS/FAILED
Objective
Action
Verification/
Remark
CB Trip Coil 1 Y phs -Q0B
-60 V
CB Trip Coil 1 B phs-Q0B
-60 V
Master trip 1 Operated-Q0B
-60 V
Master trip 2 Operated-Q0B
-60 V
Start CBF phs. R -Q0B
-60 V
Start CBF phs. Y -Q0B
-60 V
Start CBF phs. B -Q0B
-60 V
Start CBF 3 phs. -Q0B
-60 V
Block A/R-Q0B
-60 V
Note: -Q0B Center CB for 1HCB
ii- Check and verify main 1/2 “A/R Inhibit BI” records voltage
Measure at CBM relay
Description
Expected
Voltage
Main 1 A/R Inhibit
+60 V
Main 2 A/R Inhibit
+60 V
Main 1 A/R Inhibit
Note: Only applicable for
1HCB center CB
+60 V
Main 2 A/R Inhibit
Note: Only applicable for
1HCB center CB
Step
10
To normalize
Bus
Separation
relay
+60 V
Normalize Bus Separation zone 2 setting
Measured
Voltage
Confirm and
verify at relay
CBM input that
A/R Inhibit for
Main 1 and 2
available
PASS/FAILED
6. CONTIGENCY ACTION PLAN
1) Specify other source /emergency supply restoration
Example:
Probable Incident/
Tripping
Cause of Incident
/Tripping
Corrective Action
1a) Tripping
• Bay under test
• Bay not tested
Wrong Injection or
incomplete tripping
isolation
Stop testing
Report to NLDC/RCC
Request for authorization and
do investigation.
Normalize back CB.
Actual fault occurred,
and tripping by others
protection relays
Stop testing
Report to NLDC/RCC
Request for authorization and
do investigation.
Normalize back CB.
Resume testing prior to
normalize back CB or
Resume testing in other time
Stop testing
Normalize back all CT circuit
immediately
Stop Testing and normalize
the system.
Do investigation
2)CT Harming
CT open circuit
3) DC Earth Fault
appear
Improper secondary
wiring during testing
#$
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SAT Live Maintenance Certification
(Phase 2)
Testing Checklist F52CBM Circuit Breaker
Failure Protection for 275/500kV OHL/UGC
CONTENTS:
1. WORK OBJECTIVE
2. LOCATION
3. SCOPE OF WORK
3.1
Work Description
3.2
Work Program
4. RISK ANALYSIS
5. DETAILS WORK PROCEDURES (WORK INVOLVE)
5.1
Prerequisite Check (System Condition Check)
5.2
Wiring &Setting Check (F11L(M1)
5.3
Isolation / Scheme Defeat (F11L(M1)
5.4
Testing Work (F11L(M1)
5.5
Normalization & Scheme Restoration
6. CONTIGENCY ACTION PLAN
1. WORK OBJECTIVE
To perform secondary injection test for Main 1 & Main 2 Line Integrated Current
Differential Protection relay in live condition to validate Live maintenance feature
as intended design and certified the panel as “Live maintenance Work
Compliance”,
2. LOCATION
PMU: ……………………………………….
Panel Designation: ………………………
3. SCOPE OF WORK
3.1 Work Description
• To perform operational and timing test secondary injection for Main1
F11L & Main 2 F11L in live condition and apply live maintenance
feature.
• To verify all tripping output and SCADA & annunciator indication in
functional and good condition.
• To certify the panel ready to perform Preventive Live Maintenance
3.2 Work Program
Work Description
Remark
1) Preliminary check at Site/Bay/Panel for verification of CT
circuit, VT circuit, tripping circuit, Test Socket & Isolation
check list
2) Trip isolation and short CT/Open VT circuit at
F11L(M1/M2)
3) Testing F11L(M1/M2) protection relay
4) Normalize trip output and CT/VT circuit at F11L(M1/M2)
4. RISK ANALYSIS
Detail work description, the RISK of each activity and the Mitigation involved
Description
1. Testing Activity
Risk involved
Personnel
a) DC or AC supply
insulation leak may cause
Mitigation / Minimizing
Risk
Personnel
i) Use proper PPE & tools.
ii) Check insulation
Description
Risk involved
electrical shock.
b) Flashover due to wrong
termination may cause
injury.
Apparatus/Equipment
a. Damage to relays due to
testing
b. Damage of CT due to CT
open Circuit
Mitigation / Minimizing
Risk
resistance of wiring to
earth.
iii) Do not leave any cut
wires in the trucking.
Apparatus/Equipment
i) Injection values must not
exceed rated values stated
in the relay manuals.
ii) When handling relay
printed circuit board always
earth body to prevent static
voltage.
iii) Use the correct DC
voltage to energize relay
inputs.
i) Make sure shorting leads
and test plug in good
condition.
ii) Confirm function no. from
relay to terminal block is
correct.
iii) Make current
measurement to confirm
shorting done properly.
System
i) Extra care to be taken to
ensure the correct bay
under-test at both ends is
i) Wrongly implementing
live maintenance procedure identified
ii) Ensure that test plug in
in sequence
good condition
ii)DC earth fault can cause
iii) Ensure the correct
mal operation to the
relays been identified for
existing system.
iii) protection scheme is not testing for both ends.
iv) Ensure correct
fully switched off/defeated.
sequence during isolation
before perform testing with
validation
System
Tripping of live bays.
5.0 DETAILS WORK PROCEDURES (WORK INVOLVE)
5.1 Prerequisite Check (System Condition Check)
Action
To check local/remote weather in good condition
Make sure all relays in good conditions. Ensure no relay
indication operated
To make sure all required tools in good condition (meters
and shorting leads)
To make sure all test plug connection as per drawing.
To check loading for tested OHL/UGC bay at both end
and the parallel bays.
Ensure load current not less than 10% of line rating
Note: At any condition, bay under test and parallel bays
shall carry less than 50% load to allow for N-1
contingency
Prerequisite
before testing
Measure DC voltage to check for any DC earth fault
1) If there is direct DC Earth Fault. Live maintenance
shall not be proceeded
2) If the DC Earth Fault was high resistive (80%
voltage), Live Maintenance can be proceeded with
consensus from TNB. Inform to TNB management or
Head Of Unit
Inform NLDC for Live Maintenance
Transfer all bay to Reserve busbar and tested bay at
Main busbar at both stations. Set Bus Separation
zone 2 instantaneous
Remarks
5.2 Isolation / Scheme Defeat F52CBM
Step
1
Objective
Action
Verification/ Remark
To confirm
current &
voltage
input at
relay
Read & record Current and voltage measurement all phase
at F50CBM relay
Record measurement
current and voltage at
HMI relay
Phase
Current
Voltage
Red
Yellow
Blue
Step
2
To apply
isolate
tripping
F50CBM
i- Remove/Pull out Group Isolation Link for 50CBF
ii- Check and verify all tripping output and lock-out relay at
test plug 50CBF with no –ve to ground to ensure all
tripping output was isolate by group isolation link.
Description
Step
3
To apply
2nd trip
isolation
and short
CT & open
VT circuit
Expected
Voltage
Master Trip 1 -A
0
Master trip 2 - A
0
CBF Stage 2 busbar tripping
0
Intertrip remote end-A
0
Master Trip 1 -B
0
Master trip 2 - B
0
CBF Stage 2 CB center/Bus
trip
0
Intertrip remote end-A
0
Measured
Voltage
Insert test plug RTXP 14 for F50CBM.
Note: During insert test plug, F50CBM relay may operate
and indication at annunciator will trigger. Ensure no
tripping to CB
i- Check and verify from F50CBM HMI record no current
input to verify F50CBM is already isolated from CT circuit
by test plug
ii- Measure and record current circuit at Fault Recorder and
relay HMI:
Confirm and verify 0
V dc voltage output
contact for tripping at
test plug CBM.
PASS/FAILED
Confirm and verify
from F50CBM
HMI/LCD that no
current input &
voltage. Confirm
circuit continuaity to
DFR by current
measurement/reading
PASS/FAILED
Objective
Action
Phase
Current at
F50CBM
HMI
Verification/ Remark
Voltage
F50CBM
HMI
Current at
Fault
Recorder
Red
Yellow
Blue
iii- Reset relay F50CBM and ensure no relay operation.
Insert back group isolation link.
iv- Check and verify all tripping output and lock-out relay at
terminal relay with no –ve to ground to ensure all
tripping output was isolate by group isolation link.
Description
Step
4
To apply
2nd short
CT Circuit
F50CBM at
terminal
block
Expected
Voltage
Master Trip 1 -A
0
Master trip 2 - A
0
CBF Stage 2 busbar tripping
0
Intertrip remote end-A
0
Master Trip 1 -B
0
Master trip 2 - B
0
CBF Stage 2 CB center/Bus
trip
0
Intertrip remote end-A
0
Measured
Voltage
Measure and record secondary current and voltage at
terminal test block relay 50CBM
PMU A
Red
Yellow
Blue
Current
(Amp)
Voltage
Verify 0 V dc voltage
output contact for
tripping at relay
terminal CBM.
PASS/FAILED
Remove or pull out CT Shorting & VT group isolation link for
F50CBM
Phase
Confirm and verify
tripping circuit
isolation by voltage
measurement.
Current at
Fault
Recorder
Confirm and verify
CT/VT cirucit is
shorted and isolated
by AC Group
Isolaiton link.
Measure no current
and voltage input,
voltage both end and
no current
interruption to DFR
PASS/FAILED
5.3 Testing Work F52CBM
Objective
Verification/
Remark
Action
Step
6
To proceed
with functional
F50CBM
testing
Perform Pole discordance operation
Confirm and
verify no tripping
and no CBF
initiation.
Perform simulate Intertrip receive and send function
PASS/FAILED
Perform CBF function testing stage 1 operation
Perform CBF function stage 2 operation
Phase
Relay
Operation
86E1/2
Bus
Trip
CB
Operation
CBF stg.1
CBF stg.2
Pole
Discordance
Inter-trip
send
Inter-trip
Receive
* All testing using wet contact from test plug only and
supply +ve or –ve can be taken from RTXP24 87L(M1)
test plug
5.4 Normalization & Scheme Restoration F52CBM
Objective
Step
7
Ready for
normalization
Action
Reset all facia and relay operation
Verification/
Remark
Objective
!
Normalize CT
circuit and VT
circuit
Action
Insert or pull-in CT shorting & VT Group isolation link for
F50CBM.
Measure and record secondary current and voltage at terminal
test block relay 50CBM
PMU A
Phase
Current
(Amp)
Voltage
Current at
DFR
Red
Verification/
Remark
Confirm and
verify from
CT/VT terminal
F50CBM
current and
voltage input
available
voltage
PASS/FAILED
Yellow
Blue
Running Voltage
!
To normalize
CT & VT
circuit to relay
F11L(M1)
i- Remove test plug RTXP24 at F52CBM
ii- Check and verify from F52CBM HMI/LCD and recorder that
current and voltage is available
This action is to verify F50CBM already connected to CT &
VT circuit.
Phase
Current at
F50CBM
HMI
Voltage
F50CBM
at HMI
Current at
Fault
Recorder
Red
Yellow
Blue
Note:
All current input and voltage input at CBM and at fault
recorder should be available as expected. If
measurement is not as per expected value, further
investigation to be carried out.
Check and verify all tripping output and lock-out relay at test
plug relay has no –ve to ground to ensure all tripping output was
isolated by group isolation link.
Confirm and
verify from
F50CBM HMI
that current and
voltage input
available
PASS/FAILED
Objective
Action
Description
Step
10
To normalize
tripping
output
Expected
Voltage
Master Trip 1 -A
0
Master trip 2 - A
0
CBF Stage 2 busbar tripping
0
Intertrip remote end-A
0
Master Trip 1 -B
0
Master trip 2 - B
0
CBF Stage 2 CB center/Bus
trip
0
Intertrip remote end-A
0
Measured
Voltage
PASS/FAILED
i- Insert in Group Isolation Link for F50CBM
ii- Check and verify all tripping output and lock-out relay at
terminal 50CBM with –ve to ground to ensure all tripping
output was connected by group isolation link.
Description
Expected
Voltage
Master Trip 1 -A
-60 V
Master trip 2 - A
-60 V
CF Stage 2 busbar tripping
-60 V
Master Trip 1 -B
-60 V
Master trip 2 - B
-60 V
Intertrip remote end-B
Measured
Voltage
Confirm and
verify –ve dc
voltage at
output contact
for tripping and
CBF initation.
PASS/FAILED
0V
Intertrip remote end-A
CF Stage 2 CB center/bus
trip
Verification/
Remark
Confirm and
verify 0 V dc
voltage output
contact for
tripping at test
plug CBM.
0V
-60 V
Note: -Q0B Center CB for 1HCB
Step
11
To normalize
Bus
Separation
relay
Normalize Bus Separation zone 2 setting
"
6. CONTIGENCY ACTION PLAN
1) Specify other source /emergency supply restoration
Example:
Probable Incident/
Tripping
Cause of Incident
/Tripping
Corrective Action
1a) Tripping
• Bay under test
• Bay not tested
Wrong Injection or
incomplete tripping
isolation
Stop testing
Report to NLDC/RCC
Request for authorization and
do investigation.
Normalize back CB.
Actual fault occurred,
and tripping by others
protection relays
Stop testing
Report to NLDC/RCC
Request for authorization and
do investigation.
Normalize back CB.
Resume testing prior to
normalize back CB or
Resume testing in other time
Stop testing
Normalize back all CT circuit
immediately
Stop Testing and normalize
the system.
Do investigation
2)CT Harming
CT open circuit
3) DC Earth Fault
appear
Improper secondary
wiring during testing
#$
$% % %&
' (
#$
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(
' ) *+
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,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,,
- (
. -
+
)
/
$1$ (
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)
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SAT Appendix R: On Load / Commissioning Test
1.0
General Requirement ................................................................................................................ 1
a. On energizing of a plant, measurements shall be made all associated VT and
CT circuits of the plant.
1.0
General
Requirement
b. Upon commissioning, verify correct operation of point of wave opening
switching device. Verify the opening is performed at the zero crossing current
and closing at the peak voltage. TNB will assist this test by providing the
power quality analyzer and the printout. Analysis of the printout shall form
part of the test report.
c.
For voltage circuits the following secondary measurements and tests shall be
carried out at the end point e.g. MK and at the component end e.g. protection
relays, instruments, recorders etc.
All phase to phase voltage measurements
All phase to neutral voltage measurements
All phase to ground voltage measurements
All phase sequence tests
Phasing test (if a reference bay is available)
c.
For current circuits the following secondary measurements shall be carried
out at the component end e.g. protection relays, instruments, recorders etc.
All phase current measurement
All neutral current measurement
d. For primary circuits (415V – 33kV switchgear), the following measurements
and tests shall be made at the primary side of the component end.
Appropriate instruments shall be used for such high voltage measurements
and tests.
All phase to phase voltage measurement
All phase to neutral voltage measurement
Phasing test (if a reference bay is available)
e. For all protection with specific operation direction e.g. distance protection,
DEF, directional tests shall be performed. Any protection relay that requires
compensated parameters shall be set based on load measured values. (E.g.
Unbalanced current for capacitor bank, charging current for line differential,
circulation current for AVR)
f.
Circulating current method shall be used to prove stability of differential
protection e.g. transformer, busbar, line and cable differential protection.
g. Measurement shall also be made on broken delta voltages and residual
current circuit.
h. For all protection relays with built-in instrument functions, all measurement
reading available from the relay shall be recorded.
! "#
i.
All fault recorders to be manually triggered and verified.
j.
Live transfer scheme for all bays shall be tested for both conditions e.g. from
main to reserve and from reserve to main.
$ $
k.
1.0
General
Requirement
(Cont.)
For CB with synchronizing facilities all the following closing conditions shall
be tested from REMOTE and SUPERVISORY.
Live Line – Live Bus
Live Line – Dead Bus
Dead Line – Live Bus
l.
For transformer, the on load tap changer facility shall be checked e.g. parallel
operation (reactive current), independent operation, auto tap raising and
lowering.
m. For capacitor bank – CB closing via Point of wave operation shall be
recorded and verified.
n. All the above on-load tests shall be documented clearly as part of the
commissioning test report.
o. All spare bays shall also be energized and any applicable on-load tests
above shall be performed.
p. For 415 AC Board test to be carried out to ensure there is no back feed /
paralleling of two sources via load circuit. (With bus tie open and one source
feeding).
$
! "#
$ $
SAT Appendix S: SAT for Post Commissioning Test
1.0
Purpose…………………………………………………………………………………………………1
2.0
General Requirement………………………………………………………………………………….2
3.0
Roles and Responsibility………………………………………………………………………………3
4.0
Primary Equipment…………………………………………………………………………………….3
5.0
Secondary Equipment………………………………………………………………………………..14
1.0
Purpose
To provide SAT requirements / limit when carrying out post commissioning test
for all equipment in the plant.
!"
# #
a. Post commissioning test is carried out after the plant is energized.
2.0
General
Requirement
b. All test conducted shall be documented on a proper test form.
c.
The details of the testing shall be referred / specified in the respective test in
earlier Appendix for pre-commissioning test.
d. All tests shall be carried out together with those listed in the contract
document
e. There are three period of Post Commissioning testing in the plant:
i.
Test which is conducted within 1 week – 3 months as load is
connected.
ii. End of Warranty test which is conducted 8 months after
commissioning.
iii. End of Warranty test for which is conducted 8 months and 56 months
after commissioning (for primary equipment with 5 years warranty).
f.
On-load stability (minimum 10%) shall be conducted as load is connected for
circulating current to the facilities if it is not done during commissioning. E.g.
transformer using circulating of VARs, line and cable differential protection.
For AVR relays, perform setting for the permissible circulating current. This
test shall be conducted within 3 months after commissioning.
g. On-load measurement (minimum 10%) for all relays shall be conducted as
load is connected within 3 months after commissioning.
h. Live maintenance facilities certification (as per Appendix U) for 275kV and
above UGC and OHL shall be conducted as load (minimum 10%) is
connected within 3 months after commissioning. The test report shall be
endorsed by the ESE. Upon successful live maintenance certification, a
sticker stating live maintenance readiness provided by Grid Development
Department shall be displayed on the panel with the date of the certification.
i.
Physical inspection for all equipment during End of Warranty shall be
conducted as per pre-commissioning list, which includes the following items:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
x.
xi.
xii.
xiii.
Charger
Battery Banks
DC Distribution Board
Protection Panel
Control Panel
RTCC / AVR
Marshalling Kiosk
Digital Fault Recorder
Battery Alarm Test
RTU
Clients (HMI, EGW)
ESM & STS
SCADA
#
!"
# #
3.0
Roles
and
Responsibility
a. For on-load test (1 week – 3 month), test shall be conducted by contractor /
tester unless specified.
b. For End of Warranty test, test shall be conducted by TNB (unless specified in
contract) with the presence of contractor representative. Any deviation on the
results, contractor shall be fully responsible.
4.0
Primary Equipment
Equipment
Post Commissioning
1.0 Circuit
Breaker
1 week
8
Months
56
Months
Contact Resistance Test
√
√
As per precommissioning limits
Timing test
√
√
As per precommissioning limits
Insulation resistance test
√
√
•
•
Close open operation
√
√
Auto-reclose operation
√
√
As per precommissioning limits
SF6 Pressure Operation
√
√
As per precommissioning limits
√
√
As per precommissioning limits
SF6 Purity test
√
√
SF6 > 97%
SO2 content
√
√
< 12ppmv
CB Profiler
SF6 Dew Point
√
Limit
No Discharge
Must be consistent
for all phases.
• IR to be within
20% difference
from precommissioning
value
• Based on factory
routine test result/
O&M
• Within
recommended
manufacture’s
tolerance as
prescribed in
factory test
As per precommissioning limits
2
weeks
$
!"
# #
Equipment
Post Commissioning
2.0 Gas
Insulated
Substation
(GIS)
8
Months
56
Months
Disconnectors and Circuit
Breaker Contact
resistance test
√
√
Timing test
√
√
Insulation resistance test
√
√
Close open operation
√
√
Auto reclose operation
√
√
SF6 Pressure
√
√
Partial discharge /
acoustic measurement
√
√
√
√
SF6 Dew Point
!"
# #
1 week
√
Limit
•Based on factory
routine test result/
O&M
•Within recommended
manufacture’s
tolerance as prescribed
in factory test
•Must Shall be
consistent for all
phases.
• Based on factory
routine test result/
O & M.
• Within
manufacture’s
recommended /
tolerance value as
prescribed in
Routine test / FAT
• Pole spread shall
be <5ms
• To follow O&M
proposed limit
• No contact
bouncing detected
• More than 1G
• Shall be consistent
for all phases.
Within recommended
manufacture’s
tolerance as prescribed
in factory test
Within recommended
manufacture’s
tolerance as prescribed
in factory test
Within recommended
manufacture’s
tolerance as prescribed
in factory test
Based on IEC 62271203 and IEC 60270.
For PD measurement
Maximum allowable
Discharge 10pC
measured by
Conventional or UHF.
For acoustic
measurement, no
discharge should be
detected.
As per precommissioning limits.
Equipment
Post Commissioning
1 week
8
Months
56
Months
2
weeks
SF6 Purity test
√
(For all compartments
including Busbar
compartments)
√
√
2
weeks
SO2 content
√
Limit
As per precommissioning limits.
SF6 > 97% (for 8 & 56
months)
√
2
weeks
√
(For all compartments
including Busbar
compartments)
As per precommissioning limits.
< 12ppmv (for 8 & 56
months)
(For all compartments
including Busbar
compartments)
3.0
Transformer
Insulation resistance
√
All values shall exceed
800MΩ
Consistence between
phases
Polarization Index
√
As per precommissioning limits
Turns Ratio
√
As per precommissioning limits
Winding resistance (DC)
√
As per precommissioning limits
Excitation Current
√
Verification of the fan
operation, pump
operation, alarm and trip
settings of OTI and WTI
Winding Power Factor
√
As per precommissioning limits
As per precommissioning limits
√
Shall not increase
more than 20% from
pre-com value
Bushing Power Factor
√
Shall not increase
more than 20% from
pre-com value
Insulation Resistance
Core
√
As per precommissioning limits
Leakage Reactance
√
As per precommissioning limits
%
!"
# #
Equipment
Post Commissioning
1 week
Functional Test
a. Operation Check
b. Transformer
Guard Check
Oil Test
Moisture Content (ppm)
8
Months
56
Months
Limit
√
As per precommissioning limits
√
As per precommissioning limits
As per precommissioning limits
As per precommissioning limits
Neutralisation Value
(mg KOH/g)
Interfacial Tension
(mN/m)
Oil Colour Index
√
Dielectric Breakdown
Voltage (kV)
Test gap 2.5mm
Oil Power Factor
√
√
√
As per precommissioning limits
As per precommissioning limits
√
As per precommissioning limits
√
To follow TNB
Guideline Limit
√
To follow TNB
Guideline Limit
DGA
√
Using Full Gas Extraction
and Headspace Methods
Furan Analysis
4.0 Earthing
Transformer
Insulation resistance
2
weeks
√
2
weeks
√
√
All values shall exceed
800MΩ
Consistence between
phases
As per precommissioning limits
As per precommissioning limits
Shall not increase
more than 20% from
pre-com value
Polarization Index
√
√
Turns Ratio
√
√
√
√
Functional Test
a. Transformer
Guard Check
Oil Test
Moisture Content (ppm)
√
√
As per precommissioning limits
√
√
Neutralisation Value
(mg KOH/g)
Interfacial Tension
√
√
√
√
As per precommissioning limits
As per precommissioning limits
As per pre-
Winding Power Factor
!
!"
# #
Equipment
Post Commissioning
1 week
(mN/m)
Oil Colour Index
8
Months
56
Months
Limit
commissioning limits
As per precommissioning limits
√
√
√
√
√
√
As per precommissioning limits
√
√
To follow TNB
Guideline Limit
Insulation resistance
√
√
Shall not increase
more than 20% from
pre-com value
Resistance of the NER
resistor
√
√
The value shall
conform to the pre-com
specified value
(± 2%)
Insulation resistance test
√
√
Contact resistance for all
phases
√
√
IR to be within 20%
difference from precommissioning value
As per precommissioning limits
for 8 months
Dielectric Breakdown
Voltage (kV)
Test gap 2.5mm
Oil Power Factor
As per precommissioning limits
DGA
√
Using Full Gas Extraction
and Headspace Methods
5.0 NER
6.0
Disconnector
7.0 Current
Transformer
2
weeks
Auxiliary contact
alignment & timing test
Motor MCB Protection
√
√
√
√
Insulation Resistance
√
√
Capacitance
measurement
√
√
Power Factor
√
√
within 10% difference
from precommissioning value
for 56 months
As per precommissioning limits
As per MCB setting
• No Discharge
• Must be consistent
for all phases.
• IR to be within 20%
difference from precommissioning value
within 10% difference
from precommissioning value
Shall not increase
more than 20% from
pre-com value
&
!"
# #
Equipment
Post Commissioning
8.0 Voltage
Transformer
9.0 Capacitor
Bank
1 week
8
Months
56
Months
Insulation Resistance
√
√
Capacitance
measurement
√
√
CVT secondary voltage
measurement
Power Factor
√
√
√
√
√
√
√
√
√
√
√
√
Can Measurement
Point of Wave Switching
10.0 Surge
Arrester
Leakage Current
measurement
(Test done by TNB)
Limit
• No Discharge
• Must be consistent
for all phases.
• IR to be within 20%
difference from precommissioning value
within 10% difference
from precommissioning value
To be within 60 – 70
Volts ( 63.5 V )
Shall not increase
more than 20% from
pre-com value
Shall not increase
more than 20% from
pre-com value
Upon
energisation
transient
shall
be
performed to verify
correct operation of
point of wave closing
switching device. TNB
will assist this test by
providing
the
disturbance
recorder
and
the
printout.
Analysis of the printout
shall form part of the
test report.
1 week - Values less
than declared
8 months - Shall not
exceed 2% from earlier
value.
56 months - Shall not
exceed 5% from earlier
value.
11.0 Reactor
(Oil
Immersed
Type)
Insulation Resistance
√
√
As per precommissioning limits
Polarization Index
√
√
As per precommissioning limits
Winding Resistance (DC)
√
√
As per precommissioning limits
'
!"
# #
Equipment
Post Commissioning
1 week
8
Months
56
Months
Limit
Winding Power Factor
√
√
As per precommissioning limits
Oil Test
Moisture Content (ppm)
√
√
As per precommissioning limits
Neutralization Value
(mg KOH/g)
Interfacial Tension
(mN/m)
Oil Color Index
√
√
√
√
√
√
As per precommissioning limits
As per precommissioning limits
As per precommissioning limits
Dielectric Breakdown
Voltage (kV)
Test gap 2.5mm
Oil Power Factor
√
√
√
√
√
√
Insulation Resistance
√
√
As per precommissioning limits
Polarization Index
√
√
As per precommissioning limits
Winding Resistance (DC)
√
√
As per precommissioning limits
Insulation Power Factor
√
√
As per precommissioning limits
As per precommissioning limits
As per precommissioning limits
DGA
√
Using Full Gas Extraction
and Headspace Methods
12.0 Reactor
(Dry Type)
13.0
Switchyard
14.0 Metal
Clad
Switchgear
Thermal Vision Scanning
and Ultrasound to be
carried out above 20%
rating of load but less
than 3 month
All physical check
2
weeks
√
√
√
To follow TNB
Guideline Limit
Less than 10 degree c
between phases and
less than 40 degree
with ambient
As per precommissioning limits
As per precommissioning limits
Earthing Test
√
Pressure Test
√
As per precommissioning limits
CB Timing Test
√
As per precommissioning limits
(
!"
# #
Equipment
15.0 Standby
Generator
Post Commissioning
1 week
8
Months
56
Months
Limit
Insulation Resistance test
√
As per precommissioning limits
Contact Resistance test
√
As per precommissioning limits
SF6 Pressure Operation
√
As per precommissioning limits
SF6 Dew Point
√
As per precommissioning limits
SF6 Purity test
√
SF6 > 97%
Insulation Resistance
√
Shall not increase
more than 20% from
pre-com value
Check for correct
operation test
√
As per precommissioning limits
For Transformer with 5 years warranty:COMMISSIONING TEST
POST
COMMISSIONING
NON-INTRUSIVE
INSPECTION- (8
MNTHS AFTER
COMMISSION)
QUALITY & HEALTH
TEST (UPON
COMPLETE
ERECTION)
END OF WARRANTY
TEST – (4 YRS 8
MNTHS) *start after
commissioned OR 6
mnths after delivery
date to site/store
ACCEPTANCE VALUES
USING MEAN VALUE OF
COMMISSIONING TEST
AND IN SERVICE
CONDITION.
Physical Inspection as per
SAT Appendix J – 5.2 (b)
Physical inspection:
- Sign of leak
Physical Inspection as
per SAT Appendix J –
5.2 (b)
Physical Inspection as
per SAT Appendix J –
5.2 (b)
Verification of the fan
operation, pump
operation, alarm and trip
settings of OTI and WTI
Factory test results/O & M.
Within recommended
manufacture’s tolerance
as prescribed in factory
test
Verification of the fan
operation, pump
operation, alarm and trip
settings of OTI and WTI
*(use temporary
supply)
Verification of the fan
operation, pump
operation, alarm and trip
settings of OTI and WTI
Functional Test
c. Operation Check
d. Transformer
Functional Test
a. Operation
Check
Functional Test
a. Operation
Check
- Corrosive parts
- Moisture ingress
!"
# #
COMMISSIONING TEST
POST
COMMISSIONING
NON-INTRUSIVE
INSPECTION- (8
MNTHS AFTER
COMMISSION)
QUALITY & HEALTH
TEST (UPON
COMPLETE
ERECTION)
END OF WARRANTY
TEST – (4 YRS 8
MNTHS) *start after
commissioned OR 6
mnths after delivery
date to site/store
ACCEPTANCE VALUES
USING MEAN VALUE OF
COMMISSIONING TEST
AND IN SERVICE
CONDITION.
Guard Check
Absolute Moisture Content
in ppm (Not temperature
corrected)
Max 10ppm
b. Transformer
Guard Check
**(use temp supply)
Oil Test
Absolute Moisture
Absolute Moisture
Content in ppm (Not
Content in ppm (Not
temperature
temperature corrected)
corrected)
(as comm)
Max 10ppm
b. Transformer
Guard Check
Absolute Moisture
Content in ppm (Not
temperature corrected)
Acidity (ppm) /
Neutralisation Value (ppm)
≤ 0.03
Acidity (ppm) /
Neutralisation Value
(ppm)
(as comm)
Interfacial Tension (mN/m)
Interfacial Tension
(mN/m)
<72.5kV: <17.5ppm
72.5kV-170kV: <15ppm
>170kV: <12.5ppm
OLTC: <25ppm
Acidity (ppm) /
Neutralisation Value
(ppm)
<72.5kV: <0.12
72.5kV-170kV: <0.07
>170kV: <0.07
Interfacial Tension
(mN/m)
(as comm)
>30
>35
Colour
Colour
(as comm)
≤ 2.0
Dielectric Dissipation
Factor at 90°C
Dielectric Dissipation
Factor at 90°C
(as comm)
Max 0.015
Density Test
Density Test
Max 0.895 g/ml
Inhibitor Content
Inhibitor Content
Not detected
Electric Strength, kV
(breakdown voltage)
Electric Strength, kV
(breakdown voltage)
Not detected
Electric Strength, kV
(breakdown voltage)
> 60kV
(as comm)
(as comm)
!"
# #
Electric Strength, kV
(breakdown voltage)
<72.5kV: >45kV
72.5kV-170kV: >50kV
>170kV: >55kV
OLTC: >45kV
COMMISSIONING TEST
POST
COMMISSIONING
NON-INTRUSIVE
INSPECTION- (8
MNTHS AFTER
COMMISSION)
QUALITY & HEALTH
TEST (UPON
COMPLETE
ERECTION)
END OF WARRANTY
TEST – (4 YRS 8
MNTHS) *start after
commissioned OR 6
mnths after delivery
date to site/store
ACCEPTANCE VALUES
USING MEAN VALUE OF
COMMISSIONING TEST
AND IN SERVICE
CONDITION.
Polybuthene oil test for
cable box
Polybuthene oil test for
cable box
(as comm)
Max 60
Carbon content
Carbon content
Paraffinic content shall be
typically below 50% for
pure naphtenic base oil
with positive tolerance
variation of 2% is allowed
DGA
DGA
Using Full Gas
Extraction and
Headspace Methods
Using Full Gas
Extraction and
Headspace Methods
**(N/A if Tx not
commissioned)
Furan Analysis
**(N/A if Tx not
commissioned)
Electrical Test
Winding resistance (DC)
1. Within 2% of factory
measurements after
insulation temp
correction.
2. Within +5% between
phases after
correction to 75°C
No break during tap
changer operation.
Excitation Current
1. The test value of R ph
and B ph should be
within 10% of each
other and the Y ph
should not be greater
than the two other
phases.
2. Single phase
transformer values
must be within 10%
Winding resistance (DC)
(as comm)
Winding resistance (DC)
1.
Within +5%
between phases
after correction to
75°C
No break during tap
changer operation.
Excitation Current
(as comm)
Excitation Current
(as comm)
#
!"
# #
COMMISSIONING TEST
POST
COMMISSIONING
NON-INTRUSIVE
INSPECTION- (8
MNTHS AFTER
COMMISSION)
QUALITY & HEALTH
TEST (UPON
COMPLETE
ERECTION)
END OF WARRANTY
TEST – (4 YRS 8
MNTHS) *start after
commissioned OR 6
mnths after delivery
date to site/store
ACCEPTANCE VALUES
USING MEAN VALUE OF
COMMISSIONING TEST
AND IN SERVICE
CONDITION.
for all phases (same
manufacturer)
Winding Power Factor
<0.5% at 20°C
Bushing Power Factor
For C1:
1. < 0.7%.
2. Power factor for all
three phases <100%
difference between
phases.
For C2:
1. C2 bushing power
factor < 5%
Capacitance change +5%
from FAT result
Dielectric Response on
Winding (CHL)
< 1.0% (% moisture
content by dry weight)
Oil Power Factor
< 0.1% at 20°C
Sweep Frequency
Response Analysis
(SFRA)
1. Pattern for all phases
overlapping each other
except yellow phase
slightly lower at frequency
between 100kHz to 1kHz.
2. Same pattern when
compared with FAT result
or sister unit.
Insulation Resistance
(Winding)
IR at 1 minute > 1G
Insulation Resistance at
20°C (Core & Frame)
Core-Earth: 1G at 1
minute
Core-Frame: 1G at 1
minute
Frame-Earth: 1G at 1
minute
Leakage Reactance
The results must within
Winding Power Factor
(as comm)
Bushing Power Factor
For C1:
1. < 0.7%.
2. Power factor for all
three phases <100%
difference between
phases.
For C2:
1. C2 bushing power
factor < 5%
Capacitance change
+5% from FAT result
Dielectric Response on
Winding (CHL)
(as comm)
Winding Power Factor
<1.0% at 20°C
Bushing Power Factor
For C1:
1. <0.7%.
2. Power factor for all
three phases <100%
difference between
phases.
Capacitance change
+7.5% from FAT result
Oil Power Factor
(as comm)
Sweep Frequency
Response Analysis
(SFRA)
Oil Power Factor
< 0.3% at 20°C
Insulation Resistance
(Winding)
(as comm)
Insulation Resistance at
20°C (Core & Frame)
(as comm)
Insulation Resistance
(Winding)
IR at 1 minute > 500M
Insulation Resistance at
20°C (Core & Frame)
Core-Earth: 500M at
1 minute
Core-Frame: 500M
at 1 minute
Frame-Earth: 500M
at 1 minute
Leakage Reactance
(as comm)
Leakage Reactance
(as comm)
$
!"
# #
COMMISSIONING TEST
POST
COMMISSIONING
NON-INTRUSIVE
INSPECTION- (8
MNTHS AFTER
COMMISSION)
QUALITY & HEALTH
TEST (UPON
COMPLETE
ERECTION)
END OF WARRANTY
TEST – (4 YRS 8
MNTHS) *start after
commissioned OR 6
mnths after delivery
date to site/store
ACCEPTANCE VALUES
USING MEAN VALUE OF
COMMISSIONING TEST
AND IN SERVICE
CONDITION.
3% of the nameplate
values.
Oil leak test
The transformer shall be
able to withstand a
pressure of 30 kPa / 0.3
Bar from the top of
conservator filled with oil
for 24 hours with no oil
leakage and no
permanent deformation on
the structure.
Oil leak test
For Power Cables, warranty period shall be 2 years from the date of commissioning (unless
stated otherwise in the contract). EOW inspection & test to be conducted 21 months after
commissioning as follows:Test
No
1
5.0
Cable insulation
resistance test
Details
Limit
The test shall be conducted for
the conductor using a 10 kV
insulation tester. The test shall
be done for every span before
jointing works and to be
repeated for the complete
circuit.
Greater than 1Gohm for cable greater
than 500m length;
Greater than 10Gohm for cable less
than 50m length.
DAR greater than 1.5.
Consistent values between phases
Secondary Equipment
The following secondary equipment inspection and injection tests shall be performed during End Of
Warranty (EOW) Test.
All the CT circuit shall be verified in good and tightened condition. To perform thermographic
scanning and manual checking during 1st and 5th year of EOW test to identify any loose connection.
Extra care shall be given during the CT circuit checking.
5.1
Overcurrent
Scheme
The following testing and inspection shall be performed:
a.
b.
c.
d.
e.
f.
g.
!"
Check and confirm power supply unit is healthy
Check local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Measurement of CT input to relay
Confirm settings and configuration
Operational and timing test
Built in Trip circuit supervision test if in used
Confirm the operation of the tripping circuits
# #
h. Check for lock out operation
i. Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
The following testing and inspection shall be performed:
5.2 SBEF
Scheme
a.
b.
c.
d.
e.
f.
g.
Check and confirm power supply unit is healthy
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Confirm settings and configuration
Operational and timing test
Confirm the operation of the tripping circuits
Check for lock out operation
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
The following testing and inspection shall be performed:
5.3 High
Impedance
Protection
Scheme
a.
b.
c.
d.
e.
f.
g.
h.
i.
j.
Check and confirm power supply unit is healthy
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Confirm settings and configuration
Operational and Timing Test for all zones
Test on CT Supervision Circuit
Check the condition of the tripping circuits
Isolator auxiliary contact in tripping circuit for all bays
Transfer trip to remote end if applicable
Check for lock out operation
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
!"
%
5.4 Pilot
Wire
Protection
Scheme
#
$
&
The following testing and inspection shall be performed:
a.
b.
c.
d.
e.
f.
g.
h.
i.
j.
k.
l.
m.
Check and confirm power supply unit is healthy
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Check condition and integrity of pilot wire
Measurement of CT inputs to relay
Confirm settings and configuration
Functional Test
Pilot wire supervision
End to end injection tests
Inter-tripping circuit
Timing test
Confirm the operation of the tripping circuits
Check for lock out operation
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
The following testing and inspection shall be performed:
5.5 Bias
Differential
Protection
a. Check and confirm power supply unit is healthy
b. Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
%
!"
# #
Scheme
c.
d.
e.
f.
g.
h.
i.
j.
k.
l.
m.
Measurement of CT input to relay
Confirm settings and configuration
Functional Test
Operational test
Biased characteristic test
Inrush Blocking
Over-excitation / Over-fluxing if in used
Timing test
Confirm the operation of the tripping circuits
Check for lock out operation
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
The following testing and inspection shall be performed:
5.6 Line
Differential,
Phase
Comparison,
Current
Comparison
Protection
Scheme
a.
b.
c.
d.
e.
f.
g.
h.
i.
j.
k.
l.
m.
Check and confirm power supply unit is healthy
Check CB and Isolator auxiliary contacts to relay
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Check Tele-protection signals
Measurement of CT (Or VT if used) inputs to relay
Confirm settings and configuration
Functional Test
Transfer or Inter-trip tripping if available
Backup Distance check if used ( Refer to Distance Relays Tests)
Timing test
Confirm the operation of the tripping circuits
Check for lock out operation
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
The following testing and inspection shall be performed:
5.7 Distance
Protection
Scheme
a.
b.
c.
d.
e.
f.
g.
Check and confirm power supply unit is healthy
Check CB and Isolator auxiliary contacts to relay
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Check Tele-protection signals
Measurement of CT and VT input to relay
Confirm settings and configuration
Functional Test
i. Distance Reach check
ii. Timing test
iii. Power Swing Blocking operation
iv. Switch On To Fault functions
v. Voltage Transformer Supervision functions
h. Confirm the operation of the tripping circuits
i. Check for lock out operation
j. Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
The following testing and inspection shall be performed:
5.8 AR &
Synchronising
Scheme
a. Check and confirm power supply unit is healthy
b. Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
c. Measurement of VT input to relay
!
!"
# #
d.
e.
f.
g.
h.
i.
j.
Confirm settings and configuration
Functional Test
Check CB auxiliary contacts to the relay
Check CB Ready input wired to permanent positive
Operation Test with actual breaker (Auto reclose relay)
Check out for lock out operation. (Auto reclose relay)
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
The following testing and inspection shall be performed:
5.9 Breaker
Failure
Scheme
a. Check and confirm power supply unit is healthy
b. Check CB and Isolator auxiliary contacts to relay if wired
a. Confirm isolator bridging and isolator invalid status condition shall send
alarm after time delay (applicable to CBM of Digital Substation).
c. Check Local Alarms & annunciation (Fascia, SCADA, HMI,
EGW/CECOMS)
d. Measurement of CT input
e. Check protection initiation to breaker failure
f. Confirm settings and configuration
g. Operational and timing test
h. Check the condition of the tripping circuits
i. Isolator auxiliary contact in tripping circuit
ii. Transfer trip to remote end.
i. Check for lock out operation
j. Check the tripping isolation facilities (test terminal block, group isolation
link, trip link)
The following testing and inspection shall be performed for Under/Over
Frequency & Under/Over Voltage Scheme:
5.10
Demand/
Load
Shedding
Scheme
a. Check and confirm power supply unit is healthy
b. Check Local Alarms & annunciation (Fascia, SCADA, HMI,
EGW/CECOMS)
c. Measurement of VT input to relay
d. Confirm settings and configuration
e. Confirm On/Off Selector switch functionality. Ensure scheme inhibited
when switch switched off (DC supply to relay remain).
f. Operational and timing test
g. Confirm Undervoltage Blocking function
h. Confirm the operation of all relevant tripping circuits
i. Check for lock out operation
j. Check the tripping isolation facilities (test terminal block, group isolation
link, trip link)
The following testing and inspection shall be performed:
5.11 Low
Impedance
Busbar
Protection
Scheme
a.
b.
c.
a.
Check and confirm power supply unit is healthy
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Check CB and Isolator auxiliary contacts to relay
Confirm isolator bridging and isolator invalid status condition shall send alarm
after time delay (applicable to CBM of Digital Substation).
d. Measurement of CT inputs from all bays
e. Confirm settings and configuration
f. Check the condition of the tripping circuits (negative check)
g. Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
&
!"
# #
The following testing and inspection shall be performed:
5.12
Unbalanced
Capbank
Protection
Scheme
a.
b.
c.
d.
e.
f.
g.
h.
i.
j.
Check and confirm power supply unit is healthy
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Measurement of VT input to relay
Confirm settings and configuration
Operational and timing test
Functional test
Confirm the operation of all relevant tripping circuits
Check for lock out operation
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
Ensure the natural unbalanced current has been set and compensated by the
relay
The following testing and inspection shall be performed:
5.13 AVR
Scheme
5.14 Pole
Discrepancy
Relays
a.
b.
c.
d.
e.
Check and confirm power supply unit is healthy
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Measurement of CT and VT input to relay
Operational and timing test
Check the tripping isolation facilities (test terminal block)
The following functional tests shall be performed:
a.
b.
c.
d.
e.
f.
Check and confirm power supply unit is healthy
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Operational and timing test
Confirm the operation of all relevant tripping circuits
Check for lock out operation
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
The following testing and inspection shall be performed:
5.15
Overload
Capbank
Protection
Scheme
5.16
Under/Over
Voltage
a. Check and confirm power supply unit is healthy
b. Check Local Alarms & annunciation (Fascia, SCADA, HMI,
EGW/CECOMS)
c. Measurement of CT input to relay
d. Confirm settings and configuration
e. Operational and timing test
f. Confirm the operation of all relevant tripping circuits
g. Check for lock out operation
h. Check the tripping isolation facilities (test terminal block, group isolation
link, trip link)
The following testing and inspection shall be performed:
a. Check and confirm power supply unit is healthy
'
!"
# #
Capbank
Protection
Scheme
b.
c.
d.
e.
f.
g.
h.
5.17
Transducers
& Meters
The following testing and inspection shall be performed:
5.18 Bay
Controller
Check Local Alarms & annunciation (Fascia, SCADA, HMI, EGW/CECOMS)
Measurement of VT input to relay
Confirm settings and configuration
Operational and timing test
Confirm the operation of all relevant tripping circuits
Check for lock out operation
Check the tripping isolation facilities (test terminal block, group isolation link,
trip link)
a. Secondary Injection test
b. Verify that the measurement readings at meter, HMI (Digital Substation)
control center and CECOMS are consistent.
c. Accuracy test (if applicable)
The following testing and inspection shall be performed:
a. Secondary Injection test to verify switchgear operation, interlocking function
and manual synchronizing function
b. Verify the measurement function and compare readings at meter, HMI (Digital
Substation) control center and CECOMS are consistent.
c. Ensure all the hardwiring input are intact and able to publish GOOSE to HMI
and other clients
5.19 Input
and Output
IED
The following testing and inspection shall be performed:
d. Secondary Injection test for tripping function
e. Verify the measurement function and compare readings at meter, HMI (Digital
Substation) control center and CECOMS are consistent.
f. Ensure all the hardwiring input are intact and able to publish GOOSE to HMI
and other clients
(
!"
# #
SAT Appendix T: SAT Process Flowchart
1.0
2.0
3.0
4.0
5.0
6.0
7.0
8.0
Overview ................................................................................................................................... 1
Stage 1 – Multicore Termination Checks and AC/DC System ................................................. 1
Stage 2 – Component Level Testing for Primary & Secondary Equipment .............................. 2
Stage 3 – CT/VT Circuit Check, Switchgear Operation Test & Control scheme Tests ............ 2
Stage 4 – Protection scheme Tests, Stability Tests and Trip Tests ......................................... 3
Stage 5 – On Load and Post Commissioning Test ................................................................... 4
PQA & Plant Energising ........................................................................................................... 4
SAT Process Flowchart ............................................................................................................ 5
The SAT process is categorized into the following five stages:
1.0
Overview
i.
Stage 1 – Multicore
commissioning
termination
checks
and
AC/DC
system
ii.
Stage 2 – Component level testing for primary and secondary
equipments
iii. Stage 3 – CT/VT circuit check, switchgear operation test and Control
scheme test
iv. Stage 4 – Protection scheme test, stability test and trip test
v.
Stage 5 – On Load test and Post commissioning test
These stages shall be carried out as the above-mentioned sequence. For
completeness of the commissioning process PIAT (after Stage 2) and PQA (after
stage 4) will be conducted.
At this stage the following activities shall be carried out:
2.0 Stage 1 –
Multicore
Termination
Checks and
AC/DC System
a. Complete multi-core termination of the plant
b. Complete AC distribution system commissioning
c.
!"
Complete DC
commissioning.
# #
charger,
battery
bank
and
DC
distribution
board
a. At this stage all primary and secondary equipments shall be tested at the
component level.
3.0
Stage 2
– Component
Level Testing
for Primary &
Secondary
Equipment
b. Component level test for primary equipment, for example:
i.
ii.
iii.
iv.
v.
vi.
vii.
viii.
ix.
c.
CB timing tests, contact resistance etc.
Switchgear operation, Alignment, Torque test for CB, isolators and earth
switch at local etc.
Circuit resistance measurements
CT SAT tests
VT SAT tests
Isolator auxiliary contact setting and timing test
Electrical and safety clearances
Power Transformer, Earthing Transformer, NER equipments
Earth grid test
Component level test for secondary equipment, for example:
i.
ii.
iii.
iv.
v.
Secondary injection test for all protection relays
Secondary injection test for all instruments, transducers and meters
Secondary injection test for all disturbance and fault recorders
RTU local test
Verification of SCS Components in working order.
d. At the end of this Stage, all equipment in the plant has been proven to be in
good working condition.
e. Any of the primary and secondary equipment component level tests can be
carried out simultaneously.
With this, SAT of the component level testing completed and now the plant shall
be ready for PIAT.
a. At this stage, the following activities shall be completed first:
4.0
Stage 3
– CT/VT Circuit
Check,
Switchgear
Operation Test
& Control
scheme Tests
i. Secondary current circuit test by primary injection
ii. Secondary voltage circuit test by secondary voltage injection
iii. Switchgear operation test from LOCAL and REMOTE including position
indication verification at REMOTE
b. Followed by the control scheme test below:
i.
ii.
iii.
iv.
v.
c.
Switchgear Interlock test
Live transfer test
Voltage selection test
Synchronising scheme test
All SCADA test except from Control Centre.
Upon completion of communication facility test from both SCADA and
protection. Full SCADA test from supervisory shall be performed.
d. At the end of this stage all control related tests of the plant is completed and
now it is ready for final protection scheme test.
#
!"
# #
At this final stage of SAT, following activities shall be completed.
5.0
Stage
4 – Protection
scheme Tests,
Stability Tests
and Trip Tests
Firstly, protection scheme test for:
i.
ii.
iii.
iv.
v.
vi.
Auto-reclose
Counter
Annunciator/Alarm
SCADA, SCS
End to end
Fault/Disturbance recorder scheme
Secondly, protection trip test for all available protection schemes i.e.:
i.
ii.
iii.
iv.
Busbar protection
Breaker failure
Feeder protection
Transformer protection
Third, protection stability test i.e.:
i. Busbar protection stability
ii. Transformer protection stability
Finally, general check of the plant i.e.:
i. Settings check
ii. Panel Inspection
iii. Final operation and trip test
With this, SAT of the plant is completed and now the plant shall be ready for
PQA.
$
!"
# #
6.0
Stage
5 – On Load and
Post
Commissioning
Test
This stage will be conducted upon energization of the plant, following activities
shall be completed.
a. Firstly, On Load Test which is conducted immediately upon energization as
below i.e:
iv.
v.
vi.
vii.
Voltage and current measurement
Phasing Test
Directional & Stability Test
Live transfer and Synchronizing test
b. Secondly, Post Commissioning Test after energization within a month period,
for example
viii. Thermo scanning Test
ix. Leakage Current Measurement
x. Insulating Oil Test – DGA
c.
Finally, Post Commissioning Test after 8 months of energization shall be
done as End of Warranty Test, for example:
xi. Component level testing
xii. Component operation check
Upon successful completion of PQA, the plant is ready for energisation. Upon
energisation, live tests shall be carried out.
7.0
PQA &
Plant
Energising
!"
# #
8.0
SAT Process Flowchart
SAT Commissioning Process Flowchart
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PIAT
Result
FAIL
To rectify item
failed
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!"
# #
A
CT, VT Control and Circuit
Test
STAGE 3
CT & VT Secondary circuit
checks. i.e. by Primary Current
and Secondary Voltage Injection
Operation Test for all switchgear
e.g. CB, isolator, earth switch from
local and remote
Completed
No
Yes
Protection Scheme Test
Control Scheme Test e.g.
Interlock test, Live transfer test, voltage
Selection, Synchronising Scheme, etc.
STAGE 3
Protection Scheme Test
e.g. A/R Test, Annunciator Test, Counter Test,
Disturbance Recorder Scheme Test, End-ToEnd Communication Test, SCADA
STAGE 4
Trip Test
For all Protection Scheme
OK
YES
Protection Stability Test
e.g. Busbar Protection, Transformer
Protection etc
NO
OK
YES
Setting Checks, Panel Inspection, Final
Operation and Trip Test
STAGE 4
RSV
FAIL
Result
To rectify item
failed
PASS
On - Load Tests after plant commissioned
STAGE 5
Plant energization completed
Post Commissioning Test
STAGE 5
!
!"
# #