FM120024 Spectification

Specification for the
HIGH VOLTAGE MAINTENANCE

CONTRACT
at the
RUTHERFORD APPLETON
LABORATORY
CHILTON, DIDCOT
OXFORDSHIRE
PARAGRAPH INDEX
MAINTENANCE AND TESTING OF HIGH VOLTAGE EQUIPMENT
1. General Requirements
2. Hours of Work
3. Inspection of Site
4. Access to Premises
5. Records
6. Work Performance and Safety
Appendix A – Equipment Schedule
Appendix B – Maintenance Schedule
Appendix C – Inspection/Maintenance Checklists
Appendix D – Substation Earth Mat Arrangements
Appendix E – Transformer PCB Levels

SCOPE OF CONTRACT
1. GENERAL REQUIREMENTS
(a) A schedule of all equipment to be covered under this contract is given in

Appendix A.
(b) The Contractor shall provide the services of engineers for Annual Inspections
and Periodic Maintenance and Testing (6-yearly) as specified on the attached
Schedule of Maintenance and Testing (Appendix B). Inspection visit dates
shall be arranged on an annual basis, no less than 10 working days prior to
the first visit in each year.
(c) Annual Inspections shall be carried out within three months of the start date
of each year of the contract. These shall include:
 Transformer oil sample testing;
 Partial Discharge tests on all High Voltage cable boxes on Transformers
and Switchgear, bus-bars, and of cast resin Transformers;
 Check Transformer breathers and change oil and desiccant as necessary.
Replace any damaged or badly discoloured breathers;
 Inspect moisture indicators (where fitted) on switchgear;
 Testing of batteries and inspection of battery chargers. Clean batteries as
required;
 Topping up of wet cells with distilled water (water to be supplied by the
Contractor);
 Check Eye Wash bottles for content and date (new bottles will be supplied
by the Technical Officer);
 System earth tests (no disconnections to be carried out);
 Visual inspection of all switchgear including an external clean where
required. Check for hot-spots;
 Check paintwork, and, especially for outdoor equipment, touch up with
primer as required (paint to be supplied by the Contractor).
A schedule of Annual Inspections is shown in Appendix B.
There is no requirement under this contract for polychlorinated biphenyl
(PCB) tests to be carried out on Transformers. Levels from samples taken in
2005 are shown in Appendix E for all Transformers manufactured before
1987.
(d) A full report on each Annual Inspection shall be passed on to the Technical
Officer at a post inspection review meeting which shall be held no later than
two months from the date of the inspection. At this meeting any faults or non-
conformities shall be highlighted by the Contractor.
(e) Where additional works are determined necessary by the Technical Officer,
the Contractor shall provide the additional resource. These visits shall be at a
time to be agreed with the Technical Officer and may take place outside
normal working hours.
Such work shall be charged at the labour rates detailed in the Schedule of
Charges.
(f) Dates for Periodic Maintenance (6-yearly) shall be agreed between the
Contractor and the Technical Officer. It shall be the responsibility of the
Contractor to initiate a plan of all maintenance works across site.
(g) A schedule for Periodic Maintenance is shown in Appendix B. Due to the

nature of the system and loadings, much of the Periodic Maintenance may
need to be programmed for periods outside normal working hours.
(h) Switching Schedules, Risk Assessments, and Method Statements must be

sent to the Technical Officer no less than 10 working days prior to the date of
maintenance or other works so that they can be assessed and altered if
necessary.
(i) All switching shall be carried out by an AP or SAP with a current certificate for
such operations as are necessary or may occur due to technical problems or
faults. This certificate shall be no more than 5 years old. A copy of the
certificates of all (S)AP’s intended to operate on RAL equipment shall be
given to the Estates Services Authorising Engineer at the commencement of
the Contract, or prior to any new (S)AP’s being introduced to site (see also
Clause 6 (c)).
(j) Unless indicated by the Technical Officer it shall be assumed by the

Contractor that all Low Voltage supplies are to be kept in service during
maintenance through Low Voltage coupling. Where the Contractor believes
this cannot be achieved safely or otherwise, such concerns shall be
forwarded to the Technical Officer at the earliest opportunity.
(k) Requirements for specified Inspection and Maintenance Tasks are shown in
Appendix C.
(l) With the exception of Eye Wash bottles, the Contractor shall provide such
spares and replacement parts as are necessary to keep the equipment in
good working order. All spares and replacement parts shall be charged at the
standard list price less discount as detailed on the Schedule of Charges.
All prices to be quoted by the Contractor, and agreed with the Technical
Officer, prior to the work taking place.
All repairs and replacement of parts shall be charged at the labour rates
detailed in the Schedule of Charges.
(m) Where there is a need to touch-up paintwork on external equipment, red

oxide primer shall be supplied by the Contractor. Areas primed by the
Contractor shall be indicated to the Technical Officer for top-coating by RAL
staff.
(n) The Contractor shall provide a 24 hour call-out service for emergencies
between routine visits, with a response time of no more than 8 hours.
All call-outs shall be charged at the rates detailed in the Schedule of Charges.
(o) Any work or service not covered by the Contract shall be authorised in
advance by the Technical Officer and shall be charged at rates agreed
between the Technical Officer and the Contractor.
(p) The Contractor shall ensure that such manpower and other resources as are
necessary to fulfil his obligations under the Contract are available at all times
and shall exercise all reasonable skill, care, and diligence in the discharge of
all duties performed by him.
2. HOURS OF WORK
(a) The normal hours of working at the Rutherford Appleton Laboratory are:
Monday to Thursday 08:00 – 16:30
Friday 08:00 – 16:00
(b) Unless otherwise agreed between the Contractor and the Technical Officer
Annual Inspections shall be carried out between these hours. The
requirements for Periodic Maintenance shall be agreed between the
Technical Officer and the Contractor.
(c) At all times the Contractor shall report to the Technical Officer or his deputy at
the start and finish of each working day.
3. INSPECTION OF SITE
(a) It is essential that prior to tendering the Contractor visits the site to ascertain
all the necessary information as to the risks and working procedures that may
affect the tender sum. Arrangements to visit the site may be made with the
Technical Officer:
Mr. S. Bigden Tel: 01235 778125
e-mail: steve.bigden@stfc.ac.uk
(b) No claim for extra payment will be considered as a result of any

misunderstanding or lack of awareness of the risks, working procedures, or
condition of equipment at the Rutherford Appleton Laboratory.
(c) A schematic of the Rutherford Appleton Laboratory High Voltage network will
be issued to each tenderer at the time of the site visit.
4. ACCESS TO PREMISES
(a) The Contractor shall be offered reasonable access to the areas where the
equipment is located. The Technical Officer shall ensure that area
representatives are made aware of any work taking place.
(b) Access to areas which are restricted, shall be arranged through the
Technical Officer prior to work being carried out, and any specific safety
issues forwarded on to the Contractor by the Technical Officer in advance of
any Risk Assessments or Method Statements being produced.
(c) Some equipment is situated within Classified Ionising Radiation areas. Safe
Systems of Work will be issued by Health Physics prior to any such work
taking place. The Technical Officer shall ensure that the Contractor is aware
of the equipment situated in these areas for inclusion in his Risk
Assessments and Method Statements.
5. RECORDS
(a) The Contractor shall provide a full report for each Annual Inspection, and any
faults, failures, or non-conformities discovered during the visit shall be
highlighted. This report shall be, and remain, the property of STFC.
(b) The Contractor shall provide a full report for each item of equipment
maintained under Periodic Maintenance. These reports shall be passed on to
the Technical Officer at quarterly meetings following the maintenance where
any faults or non-conformities shall be highlighted.
6. WORK PERFORMANCE AND SAFETY
(a) All persons employed by the Contractor to carry out High Voltage and Low
Voltage switching shall hold an Authorised Person certificate
(b) All persons performing work under the Contract shall be fully trained and
skilled to carry out inspection and testing of High Voltage Switchgear.
(c) At the commencement of the Contract the Contractor shall supply the
Technical Officer with names, copies of certificates of competency and safety
training courses of all operatives who are to perform under the contract. The
Contractor shall keep the Technical Officer informed of any additions,
deletions, or other changes to this information throughout the duration of the
Contract.
(d) All works shall be carried out in accordance with the following legislation,
regulations, or codes of practice:
i. Health and Safety at Work Act 1974
ii. Electricity at Work Regulations 1989
iii. The Electricity Safety, Quality, and Continuity Regulations 2002
iv. The Provision and Use of Work Equipment Regulations 1998
(PUWER)
v. Management of Heath and Safety at Work Regulations 1999
vi. Reporting of Injuries, Diseases, and Dangerous Occurrences
Regulations 1995 (RIDDOR)
vii. The Ionising Radiations Regulations 1999
viii. STFC Safety Codes available at www.shepublic.stfc.ac.uk
ix. All other relevant safety legislation
(e) All operatives who are to work at the Rutherford Appleton Laboratory must
attend a site induction (held each Monday morning at 09:30) to familiarise
themselves to the specific Health and Safety requirements of the site. This is
an annual requirement.
APPENDIX A
Equipment Schedule
Area Item Type Manufacturer Quantity YOM

Sub 8 1100/400V Transformer 1250kVA Cast Resin Transformer (T21) Brentford 1 1967
400V Switchgear 2000A Air Circuit Breaker Johnson & Phillips 1 1967
400V O/C + E/F Protection Type TJV O/C Relay Reyrolle 3 1967
Restricted Earth Fault Type 283 Relay Reyrolle 1 1967
Transformer Protection Type T154 Transformer Temperature Relay TEC Systems 1 2005
Earth Mat For details see Appendix D 1967
Sub 9 11kV Switchgear 1250A Genie Evo Schneider Electric 1 2010
630A Genie Evo Schneider Electric 2 2010
200A Genie Evo Schneider Electric 2 2010
11kV O/C + E/F Protection S20 Sepam Relay Merlin Gerin 3 2010
T20 Sepam Relay Merlin Gerin 2 2010
Unit Protection Relays Solkor R/Rf Relay (R Mode) Reyrolle 2 2010
Voltage Transformer 11000/110V Cast Resin Schneider Electric 2 2010
11000/400V Transformer 2000kVA Midel Cooled Transformer (T56, 2
Schneider Electric 2010
T57)
400V Switchgear 3200A M-PACT Plus Air Circuit Breaker GE 3 2010
800A M-PACT Plus Air Circuit Breaker GE 2 2010
400V O/C + E/F Protection M-PRO 30 Relay GE 2 2010
M-PRO 17 Plus Relay GE 2 2010
HV Tripping Batteries 135 System 110V Battery Charger PB Design 1 2010
Type VN8-6 Battery Alcad 15 2010
Power Factor Correction Unit Type 4RY87 Modl. 2 2010
Sub 11kV Switchgear 1250A Genie Evo Vacuum Circuit Breaker Schneider Electric 3 2008
10 630A Genie Evo Vacuum Circuit Breaker Schneider Electric 14 2008
11kV O/C + E/F Protection S20 Sepam Relay Merlin Gerin 17 2008
Unit Protection Type R/Rf Solkor Relay Reyrolle 2 2010
11kV/400V Transformer 1000kVA Oil Cooled Transformer (T22, T23) Schneider Electric 2 2008
400V Switchgear 2000A M-PACT Air Circuit Breaker GEC Alsthom 3 1998
1250A M-PACT Air Circuit Breaker GEC Alsthom 2 1998
400V O/C + E/F Protection M-PRO 20 Relay GEC Alsthom 1 1998
M-PRO 30 Relay GEC Alsthom 2 1998
HV Tripping Battery SCV110 110V Battery Charger RWD 1 2001
Dryfit A 400 12V Battery Sonnenshein 9 2001
Earth Mat For details see Appendix D NK
Sub 11kV/400V Transformer 1250kVA Oil Cooled Transformer (T35, T36) Brush 1 1963
11 Winder 1 2001
400V Switchgear 2000A M-PACT Air Circuit Breaker GE 3 2002
11kV O/C + E/F Protection S40 Sepam Relay Schneider Electric 2 2011
T40 Sepam Relay Schneider Electric 13 2011
11kV Unit Protection Type R/Rf Solkor Relay Siemens 2 2011
11000/400V Transformer 1250kVA Oil Cooled Transformer (T24, T25, Schneider Electric 3 2007
T26, T27) Schneider Electric 1 2011
400V Switchgear 2000A M-PACT Air Circuit Breaker GEC Alsthom 5 1998
Sub 400V O/C + E/F Protection M-PRO 20 Relay GEC Alsthom 3 1998
12 M-PRO 40 Relay GE 1 2010
(Cont. HV Tripping Battery 135 System 110V Battery Charger PB Design 1 2011
) NPL 24-12 12V Battery Yuasa 9 2011
LV Tripping Battery To be installed
Sub Circuit Switchgear 1250A Genie Evo Vacuum Circuit Breaker Schneider Electric 3 2010
200A Genie Evo Vacuum Circuit Breaker Schneider Electric 2 2010
Unit Protection Solkor R/Rf Relay Reyrolle 2 2010
11000/400V Transformer 2000kVA Midel Cooled Transformer (T29, 2
T30)
HV Tripping Batteries 135 System 110V Battery Charger PB Design 1 2010
Type VN8-6 Battery Alcad 15 2010
Power Factor Correction Unit Type 4RY87 Modl. 2 2010
Sub 11kV O/C + E/F Protection Type TJV O/C Relay Reyrolle 12 1964
14 Type TJV E/F Relay Reyrolle 6 1964
† Unit Protection Type CF11 Solkor Relay Reyrolle 2 NK
Type RSG1 Solkor Relay Reyrolle 1 1964

11kV Unit Protection Type R/Rf Solkor Relay Siemens 2 2012
3.3kV Switchgear 400A LM23T Oil Circuit Breaker Reyrolle 4 1968
3.3kV O/C + E/F Protection Type TJV O/C Relay Reyrolle 8 1968
Type QT E/F Relay Reyrolle 4 1968
Type TJV Standby E/F Relay Reyrolle 1 1968
3.3kV Voltage Transformer 3300/110V Cast Resin Reyrolle 1 1968
11000/3300V Transformer 4000kVA Oil Cooled Transformer (T33) British Electric 1 1968
Transformer Co.
Transformer Protection Type B33 Buchholz Surge Relay Reyrolle 1 1968
Type B33 Buchholz Gas Relay Reyrolle 1 1968
Type B33 Winding Temperature Alarm Relay Reyrolle 1 1968
Type B33 Winding Temperature Trip Relay Reyrolle 1 1968
Type TJV Standby E/F Relay Reyrolle 1 1968
HV Tripping Battery (11kV) 135 System 110V Battery Charger PB Design 1 2011
NPL 24-12 12V Battery Yuasa 9 2011
HV Tripping Battery (3.3kV) 110V Battery Charger RWD 1 2001
NPL 24-12 12V Battery Yuasa 9 2012
Sub 11kV Switchgear Ringmaster RF2C SF6 Ring Main Unit Merlin Gerin 1 2003
16 Ringmaster CE2 SF6 Ring Main Unit 1
Merlin Gerin 2003
Extension
11kV O/C + E/F Protection VIP 300 Relay ITL 2 2003
11000/400V Transformer 1250kVA Oil Cooled Transformer (T46) Schneider Electric 1 2003
800kVA Oil Cooled Transformer (T45) Schneider Electric 1 2003

Sub 400V Switchgear 2000A M-PACT Air Circuit Breaker GE 1 2003
16 1250A M-PACT Air Circuit Breaker GE 1 2003
(Cont. 800A M-PACT Plus Air Circuit Breaker GE 1 2010
) 400V O/C + E/F Protection M-PRO 30 Relay GE 2 2003
Restricted Earth Fault Type TR121 Relay Reyrolle 2 2003
HV Tripping Batteries 30V Battery Charger SG&M 1 2003
Worthington & Co
10VR7FL 12V Battery SAFT 2 2003
5VR7FL 6V Battery SAFT 1 2003
17 11kV O/C + E/F Protection S20 Sepam Relay Schneider Electric 7 2004
Voltage Transformer 11000/110V Cast Resin VT Schneider Electric 2 2004
11000/400V Transformer 500kVA Oil Cooled Transformer (T44) Schneider Electric 1 2004
400V Switchgear (S/R115) 800A M-PACT MS31W Air Circuit Breaker GE 1 2004
Tripping Battery Series 90 30V Battery Charger PB Design 1 2004
KL18P 1.2V Ni-Cd Battery SEC 25 2004
Sub 11kV Switchgear 630A Genie Evo Vacuum Circuit Breaker (p) Schneider Electric 3 2012
18 200A Genie Evo Vacuum Circuit Breaker (p) Schneider Electric 4 2012
† 11kV O/C + E/F Protection Type S40 Sepam Relay (p) Schneider Electric 2 2012
Type T40 Sepam Relay (p) Schneider Electric 4 2012
Voltage Transformer 11000/110V Cast Resin VT (p) Schneider Electric 2 2012
11000/400V Transformer 1500kVA Midel Cooled Transformer (42, T43) ABB 2 2004
2000kVA Midel Cooled Transformer (p) Schneider Electric 2 2012
Transformer Protection Oil Thermometer (p) ? 2 2012

Sub 400V Switchgear 2500A M-PACT MN31W Air Circuit Breakers GE 3 2004
18 3200A EngelliGuard G Air Circuit Breakers 2
GE 2012
(Cont.) (p)
3200A EntelliGuard G Disconnector (p) GE 1 2012
EntelliGuard Trip Unit GT-H (p) GE 2 2012
Power Factor Correction Unit Novar 300 Alstom 2 2004
HV Tripping Battery TSU11070M-6 110V Battery Charger (p) Brooknes SSL 1 2012
Batteries? (p) ? ? 2012
LV Tripping Battery No.1 30V Battery Charger SG&M 1 2004
Worthington & Co
10VRECs Battery SAFT 2 2004
LV Tripping Battery No.2 TSU3070M-6 30V Battery Charger (p) Brooknes SSL 1 2012
Batteries? (p) ? ? 2012
Sub 11000/400V Transformer 1250kVA Oil Cooled Transformer (T31, T32) Brush 2 1970
19 400V Switchgear 2000A M-PACT Plus Air Circuit Breaker GE 3 2010
400V O/C + E/F Protection
M-PRO-50 Relay GE 3 2010
Restricted Earth Fault
LV Tripping Battery 30V Battery Charger RWD Ltd 1 2001
6V NP4-6 Battery Yuasa 5 2001
Sub 1100/400V Transformer 1500kVA Cast Resin Transformer (T1, T2) SGB Starkstrom 2 2011
20 400V Switchgear 2500A EntelliGuard G Air Circuit Breaker GE 2 2011
2500A EntelliGuard G Disconnector GE 2 2011
400V O/C + E/F Protection EntelliGuard Trip Unit GT-H GE 2 2011
Type VRT200 Cooling Fan Controller TEC Systems 2 2011
Sub Transformer Cooling Fans NK NK 4 2011
20 Earth Mat 1967
(Cont. For details see Appendix D
)
Sub 11kV Switchgear 630A SE6 Ringmaster SF6 Gas Switch Schneider Electric 3 2011
21 200A CE2 Ringmaster SF6 Gas Circuit 4
Breaker
O/C + E/F Protection Relays VIP 300 Relay ITL 4 2011
1100/400V Transformer 1250kVA Cast Resin Transformer (T4) Brentford Electric 1 1967
400V Switchgear 2000A Air Circuit Breaker Johnson & Phillips 1 1967
Type B1 E/F Relay Reyrolle 1 1967
Tripping Battery STA3040M-3 SG&M 1 2011
Worthington & Co
10 pk SP2 Battery SAFT 4 2011
6 pk SP2 Battery SAFT 2 2011
Sub 1100/400V Transformer 1250kVA Cast Resin Transformer (T5, T6) Brentford Electric 2 1967
22 400V Switchgear 2000A Air Circuit Breaker Johnson & Phillips 2 1967
800A Switch (Bus-Coupler) Johnson & Phillips 1 1967
Sub 1100/400V Transformer 1250kVA Cast Resin Transformer (T7, T8) Brentford Electric 2 1967
23 400V Switchgear 2000A Air Circuit Breaker Johnson & Phillips 2 1967
800A Switch (Bus-Coupler) Johnson & Phillips 1 1967
Sub 11kV/400V Transformer 1500kVA Oil Cooled Trans. (T38, T39, T40, South Wales 4
2002
24 T41) Trans.
Sub O/C + E/F Protection M-PRO 30 Relay GE 4 2002
24 LV Tripping Battery Series 90 30V Battery Charger PB Design 1 2002
(Cont. NP10-6 6V Battery Yuasa 5 2002
) Earth Mat NK
For details see Appendix D
Sub 11kV Switchgear RN2C Ringmaster SF6 Ring Main Unit Schneider Electric 1 2011
25 11kV O/C + E/F Protection VIP 300 Relay ITL 1 2011
1100/400V Transformer 2000kVA Cast Resin Transformer (T58) Zuccini 1 2011
400V Switchgear 3200A EntelliGuard G Air Circuit Breaker GE 2 2011
400V O/C + REF Protection EntelliGuard Trip Unit GT-H GE 1 2011
Transformer Cooling Fans NK NK 2 2011
Tripping Battery 30V Battery Charger SG&M 1 2011
Worthington & Co
Power Factor Correction Unit Type RVC ABB 1 2011
Earth Mat For details see Appendix D NK
11kV O/C + E/F Protection T40 Sepam Relay Merlin Gerin 2 2005
11000/400V Transformer 1250kVA Cast Resin Transformer (T9, T10) SGB Starkstrom 2 2005
400V Circuit Breaker 2000A M-PACT Air Circuit Breaker GE 3 2005
HV Tripping Battery ST30/10/3 30V Battery Charger Cooper 1 2005
KL11P 1.2V Ni-Cd Battery GAZ 25 2005
LV Tripping Battery Series 90 24V Battery Charger PB Design 2 2005
VN16-5 6V Battery Alcad 8 (2 x 4) 2005
Sub Earth Mat For details see Appendix D 2005
26
(Cont.
)
400V switchgear 2000A M-PACT Air Circuit Breaker GE 3 2005
Voltage Transformer 11000/110V Cast Resin (T15, T16) Schneider Electric 2 2005
11000/400V Transformer 1250kVA Cast Resin Transformer SGB Starkstrom 2 2005
11000/400V Transformer 1250/1750kVA Cast Resin Trans. (T17, T18) SGB Starkstrom 2 2006
Transformer Cooling Fans NK NK 4 2006
HV Tripping Battery 30V Battery Charger RWD 1 2006
0859-0012 6V Battery Cyclon 5 2006
40 (2 x
VN16-6 1.2V Ni-Cd Battery Alcad 2006
20)
Sub 11kV Switchgear Xiria Ring Main Unit Eaton Holec 2 2007
31 11kV O/C + E/F Protection WIC1 Relay SEG 2 2007
Sub 11000/400V Transformer 2000kVA Cast Resin Transformer (T19, T20) SGB Starkstrom 2 2007
31 Transformer Protection Type T154 Transformer Temperature Relay TEC Systems 2 2007
(Cont. VRT200 Cooling Fan Controller TEC Systems 2 2007
) Transformer Cooling Fans NK Ruck Ventilatoren 4 2006
400V Switchgear 3200A Magnum Air Circuit Breaker Eaton 3 2007
400V O/C + E/F Protection Digitrip 520i Relay Eaton 3 2007
Tripping Battery 135 System 48V Battery Charger PB Design 1 2008
ASUB-BAT-CYC8 24V Battery PB Design 2 2009
Sub 11kV Switchgear 200A CN2 SF6 Ringmaster Gas Circuit 2
32 Breaker
11000/400V Transformer 2000kVA Cast Resin Transformer (T51, T52) TMC Transformers 2 2009
400V Switchgear 3200A SACE E3 Air Circuit Breaker ABB 3 2009
400V O/C + E/F Protection SACE PR121/P Relay ABB 2 2009
Restricted Earth Fault IRI1 ER1LD Relay SEG 2 2009
Power Factor Correction Unit EPF8T Enerlux 2 2009
LV Tripping Battery 30V Battery Charger CCL 1 2009
6V NP10-6 Battery Yuasa 5 2009
Sub 11kV switchgear 630A Genie Evo Vacuum Circuit Breaker Schneider Electric 9 2008
33 11kV O/C + E/F Protection S20 Sepam Relay Merlin Gerin 3 2008
S80 Sepam Relay Merlin Gerin 4 2008
S84 Sepam Relay Merlin Gerin 2 2008
11000/400V Transformer 2500kVA Cast Resin Trans. (T47, T48, T49, 4
France Transfo 2008
T50)
Transformer Cooling Fans NK Legrand 8 2011
Sub 400V switchgear 4000A Masterpact Air Circuit Breaker Merlin Gerin 7 2008
33 1600A Masterpact Air Circuit Breaker Merlin Gerin 1 2008
(Cont. 1250A Compact Moulded Case Circuit 1
) Merlin Gerin 2008
Breaker
400V Switchgear (Cont.) 1000A Compact Moulded Case Circuit 2
Merlin Gerin 2008
Breaker
800A Compact Moulded Case Circuit Breaker Merlin Gerin 15 2008
630A Compact Moulded Case Circuit Breaker Merlin Gerin 4 2008
400V O/C + E/F Protection Micrologic 5.0 A Relay Merlin Gerin 6 2008
Micrologic 2.0 A Relay Merlin Gerin 22 2008
Restricted Earth Fault IRI1 ER5LD Relay SEG 4 2008
Power Factor Correction Unit Type RVC ABB 4 2008
HV Tripping Battery 24V Battery Charger PD Design 1 2008
1.2V LC85P Ni-Cd Battery Alcad 20 2008
LV Tripping Battery 24V Battery Charger DSE 4 2008
12V NP4-12 Battery Yuasa 8 (4 x 2) 2008
Sub 11kV Switchgear 630A CE6 Ringmaster SF6 Gas Circuit 2
Merlin Gerin 2007
34 Breaker
200A CE2 Ringmaster SF6 Gas Circuit 3
Merlin Gerin 2007
Breaker
O/C + E/F Protection Relays VIP 300 Relay ITL 3 2007
Sub 11kV Switchgear RN2C Ringmaster SF6 Ring Main Unit Merlin Gerin 1 2008
35 CN2 Ringmaster SF6 Gas Circuit Breaker Merlin Gerin 1 2009
TLF Fuses (O/C only) Merlin Gerin 2 2009
11000/400V Transformer 800kVA Oil Cooled Transformer (T53) PDT Ltd 1 2009
Transformer Protection Oil Thermometer AKM 1 2009
400V Switchgear XLBM Feeder Pillar ABB 1 2009
Sub 11kV Switchgear RN2C Ringmaster SF6 Ring Main Unit Schneider Electric 1 2011
36 11kV O/C + E/F Protection VIP 300 Relay ITL 1 2011
11000/400V Transformer 1000kVA Oil Cooled Transformer (T60) ABB 1 2006
400V Switchgear 1600A Masterpact Air Circuit Breaker Schneider Electric 1 2011
400V O/C + E/F Protection Micrologic 6.0 A Relay Schneider Electric 1 2011
Sub All equipment is the property of SSE other than cable terminations?
37
Sub 11000/400V Transformer 500kVA Oil Cooled Transformer (T34) Brush 1 1974
40 400V Switchgear 630A CM Switch GEC 1 1974
† Substation 18 is being extended at present (Completion July 2012)

Substation 14 (SSE owned) being upgraded May – November 2012
Examination of cable terminations in Substation 37 may be added to schedule at a later date

APPENDIX B
Maintenance Schedules
Annual Inspections:
Area Task Quantity Checklist
Sub 8 Partial Discharge test on Transformer 1 PD1
Annual Cast Resin Transformer inspection 1 TX4
Annual inspection of LV switchgear 1 SG1
Test and inspect Earthing System 1 ET2
Sub 9 Annual inspection of all HV and LV switchgear 10 SG1
Annual Fluid Cooled Transformer inspection 2 TX1
Transformer oil tests (Midel) 2 TX2
Partial Discharge test on HV Switchgear and # PD1
Transformer HV cable boxes
Unit Protection testing 2 PR5
Test Tripping Batteries 15 TB3
Inspect Tripping Battery Charger 1 TB1
Power Factor Correction Unit maintenance 2 PF1
Sub Annual inspection of all HV and LV switchgear 22 SG1
10 Annual Fluid Cooled Transformer inspection 2 TX1
Transformer oil tests 2 TX2
Partial Discharge test on HV Switchgear and # PD1
Transformer HV cable boxes
Unit Protection testing 2 PR5
Sub Annual inspection of all LV switchgear 3 SG1
Partial Discharge test on Transformer HV cable boxes # PD1
Partial Discharge test on HV switchgear and # PD1
Transformer HV cable boxes and cast resin transformer
Test HV Tripping Batteries 9 TB2
Inspect HV Tripping Battery Charger 1 TB1
Partial Discharge test on HV switchgear and transformer # PD1
HV cable boxes
Sub Unit Protection testing * 3 PR5
14
HV cable boxes
Unit Protection testing * 2 PR5
HV cable boxes
HV cable boxes
Inspect HV Tripping Battery Charger 1 TB1
Test Earthing System 1 ET2
Partial Discharge test on HV switchgear # PD1
Test Tripping Batteries ? TB2

Sub Test Earthing System 1 ET2
18 Power Factor Correction Unit maintenance 2 PF1
(Cont.
)
Partial Discharge test on Transformer HV cable boxes # PD1
20 Annual Cast Resin Transformer inspection 2 TX4
Partial Discharge test on Transformers # PD1
Partial Discharge test HV switchgear Transformer # PD1
Partial Discharge test on transformer HV cable boxes # PD1
Test LV Tripping Batteries 5 TB2
Test Tripping Batteries TBA

Transformers
Transformers
Transformers
Transformers
Transformers
Test LV Tripping Batteries 40 TB3
Transformers
Transformers

Sub Test and inspect Earthing System 1 ET2
32 Power Factor Correction Unit maintenance 2 PF1
(Cont.
)
Transformers
Test LV Tripping Batteries 8 (4 x 2) TB2
34 Partial Discharge test on HV switchgear # PD1
HV cable boxes
Annual Inspection of Feeder Pillar 1 SG10
HV cable boxes
Annual Inspection of Feeder Pillar 1 SG10
Sub No work required in this Substation
37
Sub Annual Fluid Cooled Transformer inspection 1 TX1

40 Transformer oil tests 1 TX2
Partial Discharge test on transformer HV cable boxes # PD1
* Will require co-ordination with Scottish & Southern Energy

# Number of tests to be determined by Contractor, but must be suitable and sufficient
to cover all aspects of the equipment
Periodic Maintenance (Year 1):
Area Item Description Quantity Checklist

Sub 11kV Circuit Breaker maintenance (Feeders to Subs 3 SG4
12 24 and 36 only)
11kV Protection Relay testing (Feeders to Subs 24 3 PR3
and 36 only)
Sub 3.3kV Circuit Breaker maintenance and oil change 4 SG3
15 3.3kV Protection Relay testing 13 PR3
Periodic Fluid Cooled Transformer inspection 1 TX5
Buchholz Relay testing and inspection 2 PR2
Transformer Temperature Relay testing 2 PR1
11kV Circuit Breaker maintenance (Feeders to Subs 10 SG4
20, 21, 22, 23, and 3.3kV transformer only + 5x
Spares)
11kV Protection Relay testing (Feeders to Subs 20, 5 PR3
21, 22, 23, and 3.3kV transformer only)
3300/110V Voltage Transformer inspection 1 VT2
Sub Periodic Cast Resin Transformer inspection and clean 2 TX6
20 400V Air Circuit Breaker and Switch maintenance 4 SG7
400V Protection Relay testing 2 PR3
Transformer Temperature Relay and Fan testing 2 PR1
Sub 11kV Switch maintenance 7 SG4
21 11kV Protection Relay testing 4 PR3
Periodic Cast Resin Transformer inspection and clean 1 TX6
400V Air Circuit Breaker and Switch maintenance 3 SG7
Sub Periodic Fluid Cooled Transformer inspection 4 TX5
Sub 11Kv Ring Main Unit maintenance 1 SG4
36 Periodic Fluid Cooled Transformer inspection 1 TX5
400V Air Circuit Breaker and Switch maintenance 1 SG7

Sub 9 11kV breaker maintenance 5 SG4
11kV Protection Relay testing 4 PR3
400V Air Circuit Breaker maintenance 5 SG7
Sub 11kV Circuit Breaker maintenance (Ring Feeders to 4 SG4
10 Sub 9 and Sub 13 and Feeders to Sub 19 only)
11kV Protection Relay testing (Ring Feeders to Sub 9 4 PR3
and Sub 13 and Feeders to Sub 19 only)
Sub 11kV Circuit Breaker maintenance 6 SG4
13 11kV Protection Relay testing (excluding Standby 5 PR3
supply from Sub 16)
Sub 11kV Circuit Breaker maintenance (Feeder to Sub 40 1 SG4
15 only)
11kV Protection Relay testing (Feeder to Sub 40 only) 1 PR3
19 400V Air Circuit Breaker maintenance 4 SG5
400V Protection Relay testing including Restricted 2 PR3
Earth Fault Relay PR4
40 Incoming LV switch maintenance 1 SG7

Sub 8 Periodic Cast Resin Transformer inspection and clean 1 TX6
Restricted Earth Fault Relay tests 1 PR4
Sub 11kV Circuit Breaker maintenance (Feeders from Sub 11 SG4
10 14, Bus-Coupler, interconnector to Sub 12, Local
Transformers, + 5x spares)
11kV Protection Relay testing (excluding Ring 10 PR3
Feeders to Sub 9 and Sub 13 and Feeder to Sub 16)
*
11000/110V Voltage Transformer inspection * 2 VT2
Sub 11kV Circuit Breaker maintenance (Feeders to Subs 6 SG4
12 8 and 11, incomer from Sub 14, interconnector to Sub
10, 900kW Rectifier, and Bus-Coupler)
11kV Protection Relay testing (Feeders to Subs 8 and 5 PR3
11, incomer from Sub 14, interconnector to Sub 10,
and 900kW Rectifier) *
Sub 11kV Circuit Breaker cable box examination (Feeders 5 SG5
14 to Subs 10, 12, and 15) *
11kV Protection Relay testing (Feeders to Subs 10, 5 PR3
12, and 15) *
Sub 11kV breaker maintenance (Incomers from Sub 14 3 SG4
15 and Bus-Coupler only )
11kV Protection Relay testing (Incomers from Sub 14 2 PR3
only) *
(Incomers from Sub 14 only) *
* Will require co-ordination with Scottish and Southern Energy


Sub 11kV Circuit Breaker maintenance (Feeder to Sub 16 1 SG4
10 only)
11kV Protection Relay testing (Feeder to Sub 16 only) 1 PR3
11 400V Air Circuit Breaker maintenance 3 SG7
Sub 11kV circuit Breaker maintenance (Feeders to Local 7 SG4
12 Transformers only + 3x spares)
11kV Protection Relay testing (Feeders to Local 4 PR3
Transformers only)
Sub 11kV Circuit Breaker maintenance (Ring Feeder to 1 SG4
15 Subs 18 & 31 only)
11kV Protection Relay testing (Ring Feeders to Sub 2 PR3
18 and Sub 31 only)
Restricted Earth Fault Relay testing 2 PR4
Sub 11Kv breaker maintenance 7 SG4
Transformer Temperature Relay testing 2 PR1(a)

Sub 11kV Circuit Breaker cable box examination (Sub 17 2 SG5
14 Feeders only) *
11kV Protection Relay testing (Sub 17 Feeders only) 2 PR3
*
17 11kV Protection Relay testing * 5 PR3
* Will require co-ordination with Scottish and Southern Energy

Sub 11kV Breaker maintenance (Ring Feeders to Sub 33 2 SG4
10 and Sub 34 only)
11kV Protection Relay testing (Ring Feeders to Sub 2 PR3
33 and Sub 34 only)
Sub 11kV Breaker maintenance (Feeder to Sub 25 only) 1 SG4
15 11kV Protection Relay Testing (Feeders to Sub 25 1 PR3
only)
Sub 11kV Switch maintenance 2 SG4
Sub 11Kv Breaker and Switch maintenance 5 SG4
Transformer Temperature Relay testing 1 PR1(a)
400V Feeder Pillar maintenance 1 SG11
APPENDIX C
Maintenance Tasks
General Requirements
(a) The checklists relevant to this Contract are shown below.
(b) Copies of the relevant checklist are to be made available to the engineers
performing the tasks for information.
(c) It is the responsibility of the Technical Officer to liaise with all managers or other
representatives of areas that may be affected by the works, particularly where
there will be interruptions in supply or a requirement to reduce loading to maintain
supplies.
(d) No High Voltage breaker or switch shall be operated live if:

 The fluid level on oil filled switchgear is below the safe limit on the sight glass;
 The gauge on gas-filled switchgear is outside the green zone;
 Any Operational Restrictions have been imposed upon the equipment with
regard to switching.
(e) Ancillary equipment shall also be inspected. These include:

 Voltage Transformers (VT’s);
 Instrument and metering Current Transformers;
 Protection relays and protection Current Transformers;
 Batteries and battery chargers.
(f) Care is required when testing equipment containing electronic devices. Such
devices shall be either disconnected or short-circuited during any testing to avoid
damage from test voltages.
(g) Any deviation from expected operation or any defects considered to present a
safety or operational hazard shall be reported to the Technical Officer.
(h) The task lists provided in this document are generic and certain items which may
not be applicable to specific items of equipment being maintained. These lists are
for guidance and are not intended to be exhaustive. All the manufacturers’
recommendations must be included.
(i) The full requirements of these relevant reference documents must be complied
with. Whilst the following list is not exhaustive, the lead reference documents are:
 STFC and RAL Safety Codes;
 BS 6626:1985 (Amended 1993) – Code of Practice for maintenance of
electrical switch/control gear for voltages above 1kV and up to and including
36kV;
 BS EN 60422:2006 – Mineral insulating oils in electrical equipment.
Supervision and maintenance guidance;
 BS EN 60255-3:1998 – Electrical relays. Single input energising quantity
measuring relays with dependent or independent time;
 BS EN 60255-5:2001 – Electrical relays. Insulation coordination for
measuring relays and protection equipment. Requirements and tests;
 BS EN 60255-6:1995 – Electrical relays. Measuring relays and protection
equipment;
 BS EN 60255-8:1998 – Electrical relays. Thermal electrical relays;
 BS EN 61810:2005 – Electromechanical elementary relays. Reliability;
 BS EN 62271-200:2004 – High-voltage switchgear and controlgear. AC
metal-enclosed switchgear and controlgear for rated voltages above 1 kV and
up to and including 52 kV;
 BS EN 50187:1997 – Gas-filled compartments for a.c. switchgear and
controlgear for rated voltages above 1 kV and up to and including 52 kV;
 BS 6133:1995 – Code of practice for safe operation of lead-acid stationary
batteries;
 BS 6132:1983 – Code of practice for safe operation of alkaline secondary
cells and batteries;
 HSE Guidance Note GS38 – Electrical test equipment for use by electricians
1995;
 HSG85 – Electricity at Work. Safe working practices 1993;
 HS(R)25 – Memorandum of Guidance on the Electricity at Work Regulations
1989;
Annual Inspections for all Substations
Checklist ET2 – Annual Substation System Earth Test
 For Annual testing of system earths clamp a stakeless ground tester around the
earth conductor leading to the earth mat and take a reading
 Where two mats are connected to the system, repeat the process
 Record the reading, or where more than one test is carried out, the highest
reading, which shall be entered into the Annual Inspection report
Checklist PD1 - Partial Discharge Examination of All High Voltage Equipment
 Transient Earth Voltage (TEV) measurement:

o Before commencing tests measure the background noise level. This can be
carried out by measuring the noise on metalwork which is not part of the
switchgear (e.g. metal door, metal fence, etc.). Record three consecutive
values of dB and counts on the metalwork and take the middle amplitude
reading as the background measurement
o Take measurements at marked points and record readings. At each point
take three readings to ensure consistency
o Record the operational state of all switchgear (HV and LV) so that a full
assessment of the results can be made.
 Ultrasonic measurement:
o Before commencing tests take a background reading
o To survey the switchgear take readings at the specified air gaps in the
switchgear (e.g. breaker spouts, air filled cable boxes, VT chambers, and
bus-bar chambers)
o Record the operational state of all switchgear (HV and LV) so that a full
assessment of the results can be made.
Checklist PF1 – Power Factor Correction Unit Maintenance
 Take internal and external temperature readings before switching off the unit
 Allow capacitors to discharge – this may take several minutes
 Clean external surfaces of unit
 Clean and vacuum all internal components including grilles
 Remove contactor guards and check for contact wear. If necessary remove any
high spots caused by arcing. If any contacts show excessive pitting report this
to the Technical Officer
 Check the capacitance of each capacitor
 Check all connections to contactors, capacitors, fuses, controllers, and reactors
 Re-energise unit and check the current and harmonics at each capacitance
step. Check voltage levels
 Check the operation of cooling fans and that they are adequately circulating the
air
Checklist PR5 – Unit Protection Relay Testing
 Where possible all breakers shall be racked into the test position for full testing
of the trip circuit
 Wipe off any dust from the outside of the relay and remove the cover
 See that the armature and contacts move freely and that the flag indicates
when the relay is operated by hand
 Record any repairs or adjustments made during the inspection
 Check all connections are tight
 Test the insulation resistance to earth of the secondary wiring with all earth-
connections, earth-links, supply fuses and links, and the Pilot Wires
disconnected. If the reading is below 2MΩ further investigation will be required
 With the Pilot Wires disconnected at both ends test the insulation resistance
between cores and to earth (ensure the applied voltage does not exceed the
rating of the cable)
 With the Pilot Wires shorted at one end measure the loop resistance from the
other end. Refer to the manufacturer’s literature to ensure the resistance is
within tolerance
 Reconnect the Pilot Wires
 Remove the trip-links and carry out overall fault-setting tests as specified by the
manufacturer
 Replace the trip-links and repeat one test to check that the HV breaker operates
 Repeat overall fault-setting tests at the other end
 Ensure all trip links are replaced and all connections, fuses, and links are
restored
Checklist SG1 – Visual Inspection of all Switchgear (HV and LV)
 Thoroughly inspect the equipment for cleanliness and check that the means of
ventilation, where provided, is not restricted. Where cleaning is necessary a
suction cleaner should be used. More stubborn dirt should be removed using
solvents, but before doing so, it is essential to check that the liquids used are
compatible with the equipment. Non-flammable and non-toxic solvents should
be chosen where possible. If this is not attainable, suitable precautions against
fire and toxic effects must be observed
 Check for signs of damage to enclosures and finishes
 Check the security of access panels or doors and visually note where possible
the condition of any gaskets on panels or doors
 Check for evidence of ingress of moisture, dust, vermin, etc.
 Feel panels to check for signs of overheating
 Check oil level (oil filled switchgear) or the gas indicator is reading in the green
zone (for SF6 switchgear)
 Where accessible and safe, check bolts for tightness and integrity. These
should be tightened to the correct torque as specified by the manufacturer
 Inspect safety signs, labels, notices, and posters fixed on or adjacent to
switchgear.
 Inspect cable boxes for any compound leaks or evidence of insulation
breakdown (hot spots)
 Inspect the condition of cables and cable ducts
 Carry out Partial Discharge on all HV switchgear, including cable boxes and
Voltage Transformers as described in Checklist PD1
 Apply an anti-rust primer to any damaged paintwork (especially where this
equipment is located outside)
Checklist SG10 – Annual Feeder Pillar Inspection
 No isolations are required for this inspection

 Clean the exterior of the Feeder Pillar using a suction cleaner and general
purpose cleaning cloths, taking care not to operate any of the switches or
buttons. More stubborn dirt should be removed using solvents, but before doing
so, it is essential to check that the liquids used are compatible with the
equipment. Non-flammable and non-toxic solvents should be chosen where
possible. If this is not attainable, suitable precautions against fire and toxic
effects must be observed
 Clean the interior of the Feeder Pillar using a suction cleaner. It is essential that
rubber attachments are used within Feeder Pillars.
 Check for evidence of ingress of moisture, dust, vermin, etc. which might lead
to malfunction or danger
 Visually inspect the condition of wiring, including all terminations, for signs of
overheating at terminals or fuse carriers
Checklist TB1 – Battery Charger Maintenance
 Isolate battery charger at adjacent spur and remove fuse. Ensure that secret
key spur units (double pole operation) are fitted to all battery chargers
 Where possible, isolate battery from charger. Where this is not possible care
should be taken when carrying out the following instructions
 Note position of any control switches
 Check all wiring and connections. Look for any signs of overheating in wiring or
other components
 Remove any accumulated dust or dirt from within the charger unit using a
suction cleaner and, if required, a suitable brush. Where the D.C. from the
batteries cannot be disconnected, care must be taken to avoid the use of metal
nozzles on the suction cleaner or bushes with metal bristle clamps
 Check the mechanical operation and condition of any control switches whilst the
battery charger is isolated
 Remove any accumulated dust or dirt from all external surfaces using a suction
cleaner and general purpose cleaning cloths. More stubborn dirt should be
removed using solvents, but before doing so, it is essential to check that the
liquids used are compatible with the equipment. Non-flammable and non-toxic
solvents should be chosen where possible. If this is not attainable, suitable
precautions against fire and toxic effects must be observed
 Restore supply and, where applicable, check charging current or that the
charging light is illuminated
 Check the electrical operation of all control switches. On completion ensure that
all control switches are reset to their normal positions as noted above
Checklist TB2 – Sealed Battery Maintenance and Testing
 Fully insulated or non-conductive tools only to be used for this task.

 Isolate battery charger at adjacent spur and remove fuse.
 Eye protection, gloves, and apron must be worn whilst working on batteries.
Where stubborn deposits need to be chiselled off the use of a full face shield
should be considered.
 Check the eye-wash bottle(s) is/are in date and replace if necessary before
commencing work. If the bottle(s) is/are in date, but the expiry date is before the
next scheduled maintenance, mark on the report that the bottle(s) needs to be
changed.
 Check all connections and links on cells for tightness and corrosion.
 Remove any dust, dirt, or acid deposits from the battery and battery terminals.
 Smear a thin layer of battery grease on battery terminals and links to prevent
corrosion.
 Carry out a State of Health (SOH) test of the battery to determine its ability to
deliver the specified performance. This is to include a measurement of cell
conductance by injecting a small a.c. current through the cell.
 Remove any accumulated dust or dirt from within the battery compartment
using a suction cleaner and, if required, a suitable brush. Care must be taken to
avoid the use of metal nozzles on the suction cleaner or bushes with metal
bristle clamps.
 Where batteries are housed in a separate cubicle from the charger, or charger
maintenance has not be scheduled to coincide with the battery maintenance,
remove any accumulated dust or dirt from all external surfaces using a suction
precautions against fire and toxic effects must be observed.
Checklist TB3 – Alkaline Battery Maintenance and Testing
 Fully insulated or non-conductive tools only to be used for this task.

 Isolate battery charger at adjacent spur and remove fuse.
 Eye protection, gloves, and apron must be worn whilst working on batteries.
Where stubborn deposits need to be chiselled off the use of a full face shield
should be considered.
 Check the eye-wash bottle(s) is/are in date and replace if necessary before
commencing work. If the bottle(s) is/are in date, but the expiry date is before the
next scheduled maintenance, mark on the report that the bottle(s) needs to be
changed.
 Check all connections and links on cells for tightness and corrosion.
 Remove any dust, dirt, or acid deposits from the battery and battery terminals.
 Smear a thin layer of battery grease on battery terminals and links to prevent
corrosion.
 Top up electrolyte in all cells
 Measure the voltage of all cells. Note, by numbering from the positive terminal
of the bank all cells that read 1.1V or lower. Where batteries are grouped, note,
by number as above, each bank with a combined voltage is equal to or less
than 1.1V per individual cell.
 Remove any accumulated dust or dirt from within the battery compartment
using a suction cleaner and, if required, a suitable brush. Care must be taken to
avoid the use of metal nozzles on the suction cleaner or bushes with metal
bristle clamps.
 Where batteries are housed in a separate cubicle from the charger, or charger
maintenance has not be scheduled to coincide with the battery maintenance,
remove any accumulated dust or dirt from all external surfaces using a suction
Checklist TX1 – Visual Inspection of Fluid Cooled Transformers
 Thoroughly inspect the transformer for any fluid leaks, particularly around joints.
Any leaking joints are to be tightened around the whole joint. This should be
reported to the Technical Officer so that the joint can be monitored
 Check the fluid level and top up as necessary following the manufacturer’s
instructions regarding cleanliness, temperature, etc.
 Inspect the colour of the breather crystals (colour dependant on crystals used).
If the breather has discoloured for more than half its length the crystals must be
replaced
 Discard any breather crystal container where it has discoloured (dirty brown)
 Inspect the oil, silicon fluid, or ester fluid level in the breather seal and top
up/replace as necessary
 Inspect the Buchholz relay float chamber where fitted. Release any gas from
the unit. If suspect, a test of the unit may be required in accordance with the
manufacturer’s instructions (see checklist PR2)
 Inspect cable boxes for any compound leaks or evidence of insulation
breakdown (hot spots)
 Carry out Partial Discharge on HV cable box as described in Checklist PD1
 Inspect the transformer externally for mechanical damage and condition of
paintwork. Minor repairs may be affected immediately. An anti-rust primer must
be applied to damaged paintwork
Checklist TX2 – Sampling and Testing of Fluid from Oil, Silicon Fluid, or Ester
Fluid (Midel) Cooled Transformers
 Care should always be taken to maintain cleanliness during the drawing of

insulating fluid samples.
 The sampling container is to be kept tightly sealed until immediately prior to
taking the sample.
 Thoroughly clean the transformer outlet from which the sample is to be drawn.
Draw off sufficient fluid to clear the outlet pipe work and discard. Rinse the
sampling container with a sufficient quantity of fluid and also discard. Take
sample ensuring that it is not contaminated and seal the sampling container
immediately.
 Insulating fluid tests are to include:
o Breakdown voltage.
o Acidity.
o Moisture content.
o Dissolved gases.
 A record of the results obtained from the sample tests shall be sent to the
Technical Officer as part of the Annual Inspection Report
Checklist TX4 – Visual Inspection of Cast Resin Air Cooled Transformers

 Check the ventilation arrangements for blockages or restriction in the airways to
and from the transformer. Check that both internal and external fans run
smoothly and quietly under thermostatic operation
 Carefully inspect the whole of the external surface of the transformer for any
signs of overheating or other damage to the paintwork. Where damage needs
to be repaired an anti-rust primer must be applied to paintwork
 Remove any accumulated dust or dirt from all external surfaces using a suction
 Where fitted check the operation of forced air fans
 Carry out Partial Discharge examination as described in Checklist PD1
Periodic Inspections for all Substations
 Isolations and earthing shall be required for many of these tasks
 Where possible, for the testing of Protection Relays, breakers shall be racked
into the Test position
Checklist PR1 – Transformer Temperature Relay and Fan Testing
 Where possible Low Voltage breakers shall be racked into the test position for
full testing of the trip circuit
 Inspect and test the temperature monitoring system (where fitted) to ensure that
the alarm and protection circuits operate at their respective pre-set temperatures.
For operation details, see manufacturer’s instruction. The following conditions
must be met:
o Temperature activation points shall be set as follows:
 95ºC – Fan On (where fitted)
 125ºC – Alarm Level
 140ºC – Critical Level (LV Trip)
o Check that at the Fan On Level any fans (internal or external) connected to
the monitoring system start to run and that Fan Controllers are operating
correctly
o At the Alarm Level check that a signal is sent to the site BMS and/or SCADA
system to notify security/site engineers that a high temperature has been
reached
o Check that at the Critical Level the Low Voltage breaker being supplied by
the transformer trips. HV tripping under such conditions is not normally a
requirement. Report to the Technical Officer where such tripping occurs
Checklist PR1(a) – Transformer Temperature Relay Testing
 Temperature monitors fitted to fluid filled transformers shall be tested to ensure

correct operation and that alarm and trip functions operate correctly
o At the Alarm Level check that a signal is sent to the site BMS and/or SCADA
system to notify security/site engineers that a high temperature has been
reached
o Check that at the Critical Level the Low Voltage breaker being supplied by
the transformer trips. HV tripping under such conditions is not normally a
requirement. Report to the Technical Officer where such tripping occurs
Checklist PR2 – Buchholz Relay Testing
 Where possible all breakers shall be racked into the test position for full testing of
the Buchholz trip circuit
 Inspect the Buchholz relay float chamber and release any gas from the unit
 Test the unit in accordance with the manufacturer’s instructions to ensure correct
operation
 Check that an alarm from this relay sends a signal to the site BMS
Checklist PR3 – Overcurrent, Earth Fault, and Standby Earth Fault Protection
Relay Testing
the trip circuit
 Thoroughly inspect the equipment for cleanliness. Where cleaning is necessary a
suction cleaner should be used lightly on internal components and a clean cloth
on external surfaces. On electro-mechanical relays, DO NOT spin the disk by
hand as this can damage the bearings
 Test each relay or a.c. trip in accordance with the manufacturers’ instructions
through secondary injection
 Identify and report any relay or series trip coil which does not operate in
accordance with the manufacturer’s curves or tables, or within the specified
tolerance
 Ensure that trip coil fuses or time limit fuses are replaced, relays reset, temporary
leads removed, and normal connections restored on completion of tests
 Ensure the fuse rating and relay settings are in accordance with the Switchgear
and Transformer Schedule (or equivalent local document)
Checklist PR4 – Restricted Earth Fault Protection Relay Testing
the trip circuit
 Thoroughly inspect the equipment for cleanliness. Where cleaning is necessary a
suction cleaner should be used lightly on internal components and a clean cloth
on external surfaces
 Test each relay in accordance with the manufacturers’ instructions
 Ensure the intertrip between the LV breaker and the HV breaker operates
 Identify and report any relay or series trip coil which does not operate in
accordance with the manufacturer’s curves or tables, or within the specified
tolerance
 Ensure that trip coil fuses or time limit fuses are replaced, relays reset, temporary
leads removed, and normal connections restored on completion of tests
 Ensure the fuse rating and relay settings are in accordance with the Switchgear
and Transformer Schedule (or equivalent local document)
Checklist SG3 – Maintenance of Oil Filled High Voltage Switchgear

 This task requires the breaker to be isolated and earthed.
 Check for damage to the enclosure or finishes
 Check the security of any access panels or doors and the condition of any
gaskets on access panels or doors
 Check for evidence of ingress of moisture, dust, vermin, etc. which might lead to
malfunction or danger
 Check dry cable boxes as described in checklist SG5. For compound or oil filled
boxes check for evidence of leaking
 Check that fire resisting barriers or seals provided on cable access points within
enclosed units are satisfactory to prevent the passage of flame, smoke, gas, or
liquid as appropriate
 Check the condition of all auxiliary wiring, including all terminations
 Check for signs of overheating and undue accumulation of dust on semi-
conductors and similar items and assemblies
 Check for damage and/or deterioration of other components and accessories
within the enclosure
 Where possible, test the continuity of metering and protection CT’s
 Check for corrosion, overheating, and pitting of primary contacts
 Maintain the oil tank:
o Remove oil tank from breaker and allow to stand under breaker whilst oil
drains from the contacts. Where possible release turbulators so that oil can
drain from these fully
o Remove oil tank and empty by pumping oil into a ‘dirty’ oil drum. Inspect
bottom of tank for particles and sediment. Clean out as necessary using lint-
free cloth (e.g. chamois leather). Rinse tank with clean oil and check again
for particles and sediment. Remove rinsing oil and wipe out tank again
o Clean off old oil from main contacts and turbulators using a lint-free cloth
o Check the condition of both fixed and moving main contacts. Inspect for
signs of corrosion, overheating, and pitting of contacts (except arcing
contacts unless excessive). Check contacts are securely fixed
o Replace turbulators ensuring they lock securely into position
o Check alignment of main contacts using the slow closing facility where fitted.
DO NOT allow the switch to latch in the closed position with the oil tank
removed.
o Check the condition of the oil tank gasket and replace if damaged
o The tank is to be kept clean of moisture and material fibre to avoid reducing
the dielectric strength of the oil. When refilling the tank with new oil, care
should be taken to avoid aeration of the oil as far as possible. Ensure that the
hose nozzle is clean if submerging this into the oil
o On completion of filling the oil tank, a short standing period shall be allowed
to let entrained air to be released from the oil before the switchgear is
energised
o Where possible, after replacement of the oil tank, check the oil level in the
sight glass. If low, top up be either using the topping up tube where fitted, or
by dropping the tank sufficiently. A further standing period shall be observed
if the oil has been topped up
 Carry out a ducter test across the main contacts
 Check earthing connections are tight and free of corrosion
 Check the operating mechanism. With the exception of the trip bar and trip coil
plungers, or unless stated otherwise in the manufacturer’s maintenance
instructions, apply light lubricating oil to bearings, shafts, and pivots, and thin
machine oil to actuating levers and rollers. A light smear of oil over the
mechanical parts of the mechanism will prevent rusting
 Check the operation of electrical and/or mechanical interlocks, closing and
tripping mechanisms, racking mechanisms, earthing gear, shutters, and
mechanical indicators
 Check the operation of contactors, relays, switches, isolators, solenoids, and
similar components
 Check damping dashpots (such as on main solenoids) and replace oil to the
correct level
 Check the operation of auxiliary contacts. Where possible clean contacts,
removing all traces of dirt and grease with solvent and re-lubricate with a thin
protective film of petroleum jelly (Chesebrough grease) or similar
 Check the correct operation of instruments, meters, anti-condensation heaters,
indicator lights, and alarm and test devices
 Check that any gas vents are clear and that all flaps are free (including those on
the external outlets)
 Check for the presence and condition of locks on control switches and control
cubicles
 Check for the presence and condition of locks on cubicle doors and panels
 Where fitted, check the levels in fluid filled cable boxes
 Check the integrity of seals on meters, fuses, and any other special equipment
 Clean the exterior of the switchgear using a suction cleaner and general purpose
cleaning cloths. More stubborn dirt should be removed using solvents, but before
doing so, it is essential to check that the liquids used are compatible with the
Checklist SG4 - Maintenance of Vacuum and SF6 High Voltage Switchgear
 This task requires the breaker to be isolated and earthed

 Check that the gas pressure in SF6 switchgear is in the green zone
 Check for damage to the enclosure or finishes
 Check the security of any access panels or doors and the condition of any
gaskets on access panels or doors
 Check dry cable boxes as described in checklist SG5. For compound filled boxes
check for evidence of leaking
 Check that fire resisting barriers or seals provided on cable access points within
enclosed units are satisfactory to prevent the passage of flame, smoke, gas, or
liquid as appropriate
 Check for signs of overheating and undue accumulation of dust on semi-
conductors and similar items and assemblies
 Check for damage and/or deterioration of other components and accessories
within the enclosure
 Where possible, test the continuity of metering and protection CT’s
 Check earthing connections are tight and free of corrosion
instructions, apply light lubricating oil or grease to bearings, shafts, and pivots,
and thin machine oil to actuating levers and rollers. A light smear of oil over the
 Check the operation of electrical and/or mechanical interlocks, closing and
tripping mechanisms, racking mechanisms, earthing gear, shutters, and
mechanical indicators
 Check the operation of contactors, relays, switches, isolators, solenoids, and
similar components
 Check the operation of auxiliary contacts. Where possible clean contacts,
removing all traces of dirt and grease with solvent and re-lubricate with a thin
 Check the correct operation of instruments, meters, anti-condensation heaters,
indicator lights, and alarm and test devices
 Check for the presence and condition of locks on control switches and control
cubicles
 Check for the presence and condition of locks on cubicle doors and panels
 Check the integrity of seals on meters, fuses, and any other special equipment
 Clean the exterior of the switchgear using a suction cleaner and general purpose
Checklist SG5 – Inspection of High Voltage Cable Boxes
 Ensure cable is earthed

 Clean the exterior of the cable box before removing the cover
 Before carrying out any cleaning within the cable box check the cores for any
signs of Partial Discharge (white powder). If any is found, report the matter to the
Technical Officer.
 Check the condition of the cable and gland, and that the cable has been made
off with the correct clearances between cores
 Using a suction cleaner and general purpose cleaning cloths remove any
contamination. More stubborn dirt should be removed using solvents, but before
Checklist SG7 – Maintenance of Low Voltage Air Circuit Breakers
 Rack out the breaker to ensure it is disconnected from any supplies, including
tripping batteries.
 Ensure that the operating mechanism springs (where fitted) are discharged.
 Clean both the exterior and interior of the switchgear using a suction cleaner and
general purpose cleaning cloths. More stubborn dirt should be removed using
compatible with the equipment. Non-flammable and non-toxic solvents should be
chosen where possible. If this is not attainable, suitable precautions against fire
and toxic effects must be observed
 Remove flash guards and examine the condition of the contacts. Clean contacts,
where accessible, removing all traces of dirt and grease with solvent. Remove
any high points due to arcing as require. Where pitting is excessive, ensure this
is recorded on the report. Re-lubricate with a thin protective film of petroleum jelly
(Chesebrough grease) or similar
 Where possible, check the operation of the main contacts
 If excessive pitting is discovered, test the conductivity of the contacts. Where this
reading is high, report immediately to the Technical Officer
 Where dashpots are fitted:
o Check the setting of the dashpot;
o Remove the dashpot and drain the oil;
o Wipe out the pot and dry the plunger using a clean cloth, removing any
sediment. Rinse with clean oil if necessary. Take extra care to remove oil
from the screw thread as this may induce siphoning when the dashpot is
replaced
o Replenish with dashpot oil. Insert the plunger and check operation. Wipe off
any new oil from the threads
o Replace dashpots to their original settings;
o Check operation of trip bar
instructions, apply light lubricating oil or grease to bearings, shafts, and pivots,
and thin machine oil to actuating levers and rollers. A light smear of oil over the
 Check operation of interlock
 Check condition of isolating contacts. Clean and re-grease with a thin protective
film of petroleum jelly (Chesebrough grease) or similar as necessary
Checklist SG8 – High Voltage Control Panel Maintenance
 Beware: Voltages up to 110V DC may exist within control cubicles

 Clean the exterior of the control panel using a suction cleaner and general
 Open each control cubicle in turn and clean using a suction cleaner. It is
essential that rubber attachments are used when DC voltages may exist.
 Check the condition of wiring, including all terminations
 Check for signs of overheating, damage and/or deterioration of components and
accessories within the enclosure
 Replace any lamps that are not working
Checklist SG11 – Periodic Feeder Pillar Inspection
 Clean the exterior of the Feeder Pillar using a suction cleaner and general
 Clean the interior of the Feeder Pillar using a suction cleaner. It is essential that
rubber attachments are used within Feeder Pillars.
 Check for evidence of ingress of moisture, dust, vermin, etc. which might lead
to malfunction or danger
 Visually inspect the condition of wiring, including all terminations, for signs of
overheating at terminals
 Remove each fuse carrier and:
o Check for signs of overheating
o Check fuse connections are tight
o Where necessary clean sliding contacts and re-lubricate with a thin
Checklist TX5 – Periodic Inspection of Fluid Cooled Transformers
 The transformer must be isolated and earthed before this task can be carried out
 Thoroughly inspect the transformer for any fluid leaks, particularly around joints.
Any leaking joints are to be tightened around the whole joint. This should be
reported to the Technical Officer so that the joint can be monitored
 Check the fluid level and top up as necessary following the manufacturer’s
instructions regarding cleanliness, temperature, etc.
 Where possible, open and inspect cable boxes checking that they are clean and
dry. On compound filled boxes check for any compound leaks or evidence of
insulation breakdown (hot spots)
 Check bolts for tightness and integrity. These should be tightened to the correct
torque as specified by the manufacturer
 Inspect the transformer externally for mechanical damage and condition of
paintwork. Minor repairs may be affected immediately. An anti-rust primer must
be applied to damaged paintwork
Checklist TX6 – Internal Inspection of Cast Resin Air Cooled Transformers
 The transformer must be isolated and earthed before this task can be carried out.
 Check the condition of access doors, including locks, interlocks, hinges, and the
general condition of the doors and interlocks
 Where accessible, check all bolted connections for tightness and integrity.
Connections and cable terminations should be tightened to the correct torque as
recommended by the manufacturer.
 Remove any accumulated dust or dirt from cooling fins, insulating surfaces, and
any heat dissipating areas using either a suction cleaner and suitable cleaning
cloths, or, wearing suitable eye and respiratory protection, by blowing clean with
compressed air (free from both oil and water) at a maximum pressure of 5 bar.
Particular attention should be given to the cleaning of insulators, the tap change
link board (where fitted), and any horizontal surfaces. Where necessary, the
whole transformer unit should be washed with clean warm water – the use of
liquid cleaners or detergent additives is not permitted. The unit should then be
dried using ‘dry’ compressed air before it is re-energised.
 Check the condition of all control wiring and devices such as thermistors and
other types of temperature detector. Ensure all control wiring is suitably fixed and
is clear of any potentially hot surfaces
 Check the condition of internal forced air fan units (where fitted) and test run
 Where it is suspected that maintenance operations have allowed moisture to
condense on to the transformer, the insulation to earth of the low voltage
windings are to be tested. A reading in excess of 50MΩ is required before the
transformer can be re-energised.
 Where possible place the High Voltage breaker into test position and test the
operation of transformer door switches, ensuring that they trip the High Voltage
breaker supplying the transformer, and any other devices coupled via intertrips.
Where this is not possible, use a continuity meter to measure the contact
operation in the LV panel of the HV breaker
Checklist VT1 – Inspection and Testing of Fluid Filled Voltage Transformers
 The cable or bus-bar being monitored by the Voltage Transformer (VT) must be
isolated and earthed before this task can be carried out
 Rack out VT and, using bespoke lifting gear (where applicable), lift out VT.
 Using required lifting gear lift cover plate and allow to drain
 Empty fluid from tank by pumping oil into a ‘dirty’ oil drum. Inspect bottom of tank
for particles and sediment. Clean out as necessary using lint-free material (e.g.
chamois leather). Rinse tank and VT (where possible) with clean oil and check
again for particles and sediment. Remove rinsing oil and wipe out tank again
 Where possible, check all internal wiring and connections, and check for any
signs of overheating or other damage
 The tank is to be kept clean of moisture and material fibre to avoid reducing the
dielectric strength of the oil. When refilling the tank with new oil, care should be
taken to avoid aeration of the oil as far as possible. Ensure that the hose nozzle
is clean if submerging this into the oil
 On completion of filling the oil tank, a short standing period shall be allowed to let
entrained air to be released from the oil before the switchgear is energised.
 Where possible, after replacement of VT into oil tank, check the oil level in the
sight glass. Top up or drain as necessary. A further standing period shall be
observed if the oil has been topped up.
 Check condition of fuses.
 Test VT continuity across windings and record the reading.
 AC Pressure Test the primary at 12kV for 1 minute (only where the primary
windings are unearthed). 500V Insulation Resistance Test the secondary (LV)
winding to earth.
 Clean the exterior of the VT using a suction cleaner and general purpose
Checklist VT2 – Inspection and Testing of Cast Resin Voltage Transformers

 Ensure the breaker associated with the Voltage Transformer (VT) is isolated and
earthed
 Open the VT compartment and clean the interior using a suction cleaner and
general purpose cleaning cloths. More stubborn dirt should be removed using
compatible with the equipment. Non-flammable and non-toxic solvents should be
chosen where possible. If this is not attainable, suitable precautions against fire
and toxic effects must be observed
 Check all internal wiring and connections, and check for any signs of overheating
or other damage
 Remove each fuse and check for wear-and-tear or other damage
Additional Works Guidance
These are for works outside the remit of this contract,
but for which the Contractor may be asked to cost
Checklist TX3 – Internal Work on Oil, Silicon Fluid, or Ester Fluid (Midel) Cooled
Transformers
 The transformer must be isolated and earthed before this task can be carried out.
 Ensure suitable lifting equipment is available for removing the transformer cover
plate. Where conservators are fitted, these will need to be drained and maybe
moved before any attempt can be made to remove the transformer cover.
Enough fluid must be removed to ensure the level is below the top of the
transformer. If the fluid can be stored in clean containers, this same fluid can be
returned to the transformer after the works are completed.
 Facilities shall be at hand in case of inclement weather to ensure the transformer
is protected from any precipitation or dust carried by the wind.
 Ensure the cover plate is clean and free from any dust, grit, tools, or any other
items that could possibly fall into the transformer vessel during the lifting process.
 Once removed the cover plate shall be lowered onto a stable stand that will keep
the underside dry and free from any dirt.
 Check condition of gasket or seal (where fitted) and replace if necessary.
 Remove the paper shield if fitted to gain access to the transformer. This shield
must be stored where it will remain dry and free from any contaminants.
 All tools used must be fitted with lanyards and attached to the engineer’s wrist,
belt, or other securing point so that they cannot be dropped into the transformer
vessel. Extreme care must also be taken not to drop any other items into the
transformer vessel.
 Where accessible, check all bolted connections for tightness and integrity.
Connections and cable terminations should be tightened to the correct torque as
recommended by the manufacturer.
 As well as carrying out required work, visually check the condition of all internal
components including windings, tails, tap changer, bushings, seals, and internal
surfaces of vessel (checking for corrosion).
 Where fitted, ensure the paper shield is replaced over the transformer before the
cover plate is refitted.
 Cover plate bolts should be tightened to the correct torque as recommended by
the manufacturer.
 Replace conservator (where fitted) and top up fluid to the required level on the
sight glass.
 Check for leaks around cover plate and connections to conservator or Buchholz
connections (where fitted).
Underground power cable work

 Before any work can proceed a Statement of Service Locations (Permit to Dig)
shall be obtained. Directions given on the Statement must be followed
 All excavations shall be securely cordoned
 Where known services exist, hand digging shall always be preferred, especially
where other live cables exist
 Before working on any underground power cable a cable identifier (i.e. Lee
Vaughan) shall be used to identify the cable
 Before any attempt is made to work on any underground power cable it shall be
spiked to prove dead. Spiking shall only be carried out by an (Senior) Authorised
Person (Electrical)
APPENDIX D
Substation Earth Mat Arrangements
Mat Test Point(s) Pins Test

Sub Mat Location Drawing No.
Number Area Position No. Covers Rods
Sub 8 EEM/S08/A NK Believed to be under Building R9. No details NK N N
Sub 9 EEM/S09/A Sub 9 LV Room West wall East of Building R25 at junction of Road 5 and 10 N N
EEM/S09/B Sub 9 LV Room West wall Road 9 11 N N
EEM/S09/C Sub 9 LV Room West wall Sub 9 Transformer Room 4 Y N
Sub EEM/S10/A Sub 10 HV Room HV Duct (West) East of Substation 10 near Road 12. Unclear if NK N N
10 EEM/S10/B Sub 10 HV Room HV Duct (East) arrangement is one mat or two. No details NK N N
Sub
EEM/S11/A R5.1 main hall North wall by LV Board North of Building R5.1. Details poor 5* Y N
11
Sub EEM/S12/A Sub 12 HV Room South Wall NK Y N
North of Substation 12 in parking area and soft
12 EEM/S12/B Sub 12 HV Room South Wall NK Y N
EEM/S12/C Sub 12 HV Room NK Transformer T27 Compound 4 Y N
Sub EEM/S13/A Sub 13 LV Room West Wall West of Building R25 at the junction of Road 15 10 N N
13 EEM/S13/B Sub 13 LV Room West Wall and Road 10 10 N N
EEM/S13/C Sub 13 LV Room NK Transformer T29, T30 Compound 4 N N
Sub EEM/S15/A Sub 15 HV Room West Wall South of Substation 15 in road NK Y N
15 EEM/S15/B Sub 15 HV Room West Wall West of Substation 15 in road 6 Y N
Sub Within Substation 16 Transformer compound. No

EEM/S16/A NK NK 4 Y N
16 details
Sub Believed to be at southeast corner of Building

EEM/S17/A NK NK NK Y? N
17 R79. No details
Sub Within Substation 18 Transformer compound. No

EEM/S18/A Sub 18 LV Room West wall 4 Y N
18 details
Sub EEM/S19/A A5 Lower P/R North wall behind LV Brd 6* Y N
North of Building R26 in Road. Details poor
19 EEM/S19/A A5 Lower P/R North wall behind LV Brd 6* Y N

Sub
EEM/S20/A NK NK No earth mat located NK NK N
20
Sub In bank near southwest corner of Building R55.
EEM/S21/A NK NK 8* Y N
21 Details poor
Sub
EEM/S22/A NK NK In bank to the north of Building R55. Details poor 3* Y N
22
Sub
EEM/S23/A NK NK In bank to the north of Building R55. Details poor 8* Y N
23
Sub Shown in bank outside Building R5.5. Details
EEM/S24/A NK NK NK NK N
24 poor
Sub May now be located under Building R5.5. Details

25 poor
Sub West wall by Bat

EEM/S26/A Sub 26 LV Room 6 Y N
26 Chargers West of Building R80. Unclear if arrangement is
West wall by Bat one mat or two. Details poor
EEM/S26/B Sub 26 LV Room 6 Y N
Chargers
Sub EEM/S27/A Sub 27 LV Room
West wall by Bat
6 Y N
27 Chargers West of Building R80. Unclear if arrangement is
West wall by Bat one mat or two. Details poor
EEM/S27/B Sub 27 LV Room 6 Y N
Chargers
Sub EEM/S28/A Sub 28 LV Room East wall by Bat Chargers East of Building R80. Unclear if arrangement is 6? Y N
28 EEM/S28/B Sub 28 LV Room East wall by Bat Chargers one mat or two. Details poor 6? Y N
Sub EEM/S29/A Sub 29 LV Room East wall East of Building R80. Unclear if arrangement is NK NK N
29 EEM/S29/B Sub 29 LV Room East wall one mat or two. Details poor NK NK N
EEM/S30/A Sub 30 HV Room West wall behind HV Brd On ISIS Mound. Area redeveloped as part of high NK N N
Sub
EEM/S30/B Sub 30 HV Room West wall behind HV Brd level emergency exit. Details poor NK N N
30
Sub EEM/S31/A Sub 31 HV Room West wall behind HV Brd East of Building R80 in the soft. Unclear if 9* Y N
31 EEM/S31/B Sub 31 HV Room West wall behind HV Brd arrangement is one mat or two. Details poor 9* Y N
Sub EEM/S32/A Sub 32 LV Room North wall Believed to be to the north of Building R92. No NK NK N
32 EEM/S32/B Sub 32 LV Room North wall details NK NK N
Sub Sub 33 LV Room

EEM/S33/A East wall NK NK N
33 1
Mat not located
Sub 33 LV Room
EEM/S33/B West wall NK NK N
2
Sub Configuration confusing as Diamond Transformer
34 also sited in same compound. No details

Sub Believed to be located outside Transformer

35 Room. No details
Sub EEM/S36/A Sub 36 HV Comp. West side of Transformer In the soft, east of Sub 36 4 Y N
36 EEM/S36/B Sub 36 HV Comp. West side of Transformer In the soft, south of Sub 36 4 Y N
Sub
EEM/S40/A Sub 40 LV Area Adjacent to LV Board Southeast corner of Building R40. Details poor 6* Y N
40
* Number of pins found and believed to be part of the substation earth mat
APPENDIX E
Polychlorinated Biphenyl (PCB) levels in Transformers
manufactured before 1987
Sub Transformer Manufacturer YOM ppm (2005)
11 T35 Brush 1963 2
British Electric
15 T33 1968 7
Transformer Co.
19 T31 Brush 1970 7

T32 Brush 1970 16
40 T34 Bush 1974 1
Notes:
1. PCB levels in Transformers manufactured between 1987 and 2005 (T28, T36,
T38, T39, T40, T41, T42, T44, T45, and T46) have readings of 1ppm or less.
2. Transformers manufactured after 2005 (T22, T23, T24, T25, T26, T29, T30, T53,
T54, T55, T56, T57, and T60) have not been tested

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What equipment is covered under the maintenance contract?

What equipment is covered under the maintenance contract?

What types of inspections and maintenance are required annually?

What types of inspections and maintenance are required annually?

Specification for the

HIGH VOLTAGE MAINTENANCE

6. Work Performance and Safety

Appendix A – Equipment Schedule

Appendix B – Maintenance Schedule

Appendix C – Inspection/Maintenance Checklists

Appendix D – Substation Earth Mat Arrangements

Appendix E – Transformer PCB Levels

(a) A schedule of all equipment to be covered under this contract is given in

(g) A schedule for Periodic Maintenance is shown in Appendix B. Due to the

(h) Switching Schedules, Risk Assessments, and Method Statements must be

(j) Unless indicated by the Technical Officer it shall be assumed by the

(m) Where there is a need to touch-up paintwork on external equipment, red

(b) No claim for extra payment will be considered as a result of any

6. WORK PERFORMANCE AND SAFETY

Area Item Type Manufacturer Quantity YOM

Area Item Type Manufacturer Quantity YOM

Area Item Type Manufacturer Quantity YOM

Area Item Type Manufacturer Quantity YOM

† Substation 18 is being extended at present (Completion July 2012)

Examination of cable terminations in Substation 37 may be added to schedule at a later date

Area Task Quantity Checklist

Area Task Quantity Checklist

Area Task Quantity Checklist

Sub Annual Fluid Cooled Transformer inspection 1 TX1

* Will require co-ordination with Scottish & Southern Energy

Area Item Description Quantity Checklist

Area Item Description Quantity Checklist

Area Item Description Quantity Checklist

* Will require co-ordination with Scottish and Southern Energy

Area Item Description Quantity Checklist

Area Item Description Quantity Checklist

Area Item Description Quantity Checklist

(d) No High Voltage breaker or switch shall be operated live if:

(e) Ancillary equipment shall also be inspected. These include:

Checklist ET2 – Annual Substation System Earth Test

Checklist PD1 - Partial Discharge Examination of All High Voltage Equipment

 Transient Earth Voltage (TEV) measurement:

Checklist PF1 – Power Factor Correction Unit Maintenance

Checklist PR5 – Unit Protection Relay Testing

Checklist SG1 – Visual Inspection of all Switchgear (HV and LV)

Checklist SG10 – Annual Feeder Pillar Inspection

 No isolations are required for this inspection

Checklist TB1 – Battery Charger Maintenance

Checklist TB2 – Sealed Battery Maintenance and Testing

 Fully insulated or non-conductive tools only to be used for this task.

Checklist TB3 – Alkaline Battery Maintenance and Testing

 Fully insulated or non-conductive tools only to be used for this task.

Checklist TX1 – Visual Inspection of Fluid Cooled Transformers

 Care should always be taken to maintain cleanliness during the drawing of

Checklist TX4 – Visual Inspection of Cast Resin Air Cooled Transformers

Checklist PR1 – Transformer Temperature Relay and Fan Testing

Checklist PR1(a) – Transformer Temperature Relay Testing

 Temperature monitors fitted to fluid filled transformers shall be tested to ensure

Checklist PR2 – Buchholz Relay Testing