precommissioning procedures of testing & commissioning

A. INTRODUCTION

The check list is intended to provide information to commissioning engineer/technician who are assigned to inspect the contractor work and witness commissioning testing on behalf of SEC to verify that substation and transmission line equipment and system are acceptable as per SEC- standard and specifications. The listing of commissioning checks and tests are based on the SEC- Commissioning standard.(attachment#9)

ITEM NUMBER EQUIPMENT

1.0 Oil Filled Power Transformers 2.0 Shunt Reactors 3.0 Bushings Inspection and Testing 4.0 Surge Arrestors 5.0 Station Service Transformers 6.0 Neutral Earthing Resistors 7.0 Current Transformers 8.0 Potential Transformers 9.0 Capacitive Voltage Transformers

10.0 Coupling Capacitor Voltage Transformers 11.0 Gas Insulated Switchgear (GIS) 12.0 Metal Clad Switchgear 13.0 Metal Enclosed Bus Duct 14.0 Indoor and Outdoor Bus Structures 15.0 Indoor Circuit Breakers 16.0 Outdoor Circuit Breakers 17.0 Disconnect and Grounding Switches 18.0 Circuit Switchers 19.0 LV Switchgear (110/220 V) 20.0 230 kV and 380 kV XLPE Cables 21.0 230 kV and 380 kV LPOF Cables 22.0 110 kV, 115 kV and 132 kV XLPE Cables 23.0 110 kV, 115 kV and 132 kV LPOF Cables 24.0 69 kV XLPE Cables 25.0 13.8 kV and 33 kV XLPE Cables 26.0 LV Cables 27.0 Control Cables 28.0 Pilot Cables 29.0 Over Head Lines 30.0 Protection and Control 31.0 station Batteries 32.0 Battery Chargers 33.0 AC Distribution Panels 34.0 DC Distribution Panels 35.0 LVAC Auto-Transfer Schemes/Switches 36.0 Grounding Systems 37.0 Switchgear Air Compressor Systems

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PRE-COMMISSIONING TEST PROCEDURE

Index Number: T-PreCom-1000-R0

Revision Number: 00

Prepared By: Pre-Commissioning Committee

Original Issue Date: 2003-06-17

Revised By: ــ

Revision Date:

Recommended By: Mohammad S. AL-Rafaa

Page Number: 1 of 96

Title:

PRE-COMMISSIONING TEST PROCEDURES FOR SEC

TRANSMISSION ELECTRICAL INSTALLATIONS Approved By:

I.Y. Al-Hamoudi, Vice President CTA

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PRE-COMMISSIONING TEST PROCEDURE PART II

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38.0 HVAC Systems 39.0 Dry Type Transformers 40.0 Fire Detection and Suppression Systems 41.0 Civil Work 42.0 Static VAR Compensation Systems

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1.0 Oil Filled Power Transformers (Standard Reference is IEC 60076 and relevant SEC Transmission Specifications)

1.1 Mechanical Checks and Visual Inspections

ITEM DESCRIPTION DONE REMARKS

1. Check the impact recorder for any abnormal impact during transit.

2. Check all components are installed.

3. Check for quality of paint, lifting lugs, quality of weld areas, rust spots and wheel stoppers.

4. Check nameplates information (visible location) as per contract specifications.

5. Check tightness of all bolts (torque wrench method).

6. Check that all grounding is securely connected (two grounding connections to main tank are required).

7. Check that the piping to Buchholz relay has proper slope.

8. Check that the tank pressure is positive, if applicable.

9. Check that the valves between the main tank and radiators are open.

10. Check the HV, LV and TV (if applicable) bushings for damage and completeness.

11. Check for correct color and quantity of desiccant (moisture absorbing media) in breathers. Check for correct breather oil levels.

12. Check heaters and humidity meters in local panel are at correct settings.

13. Check that phase marking in cable box matches with GIS and cables.

14. Check all pipes, hoses and fan protection (not rubber or plastic).

15. Check the vertical and horizontal clearances of live parts to adjacent grounded points conform to standard.

16. Check integrity of diaphragm/air bag in the conservator.

17. Perform all of the manufacturer’s specific checks.

18. Check labeling of all auxiliary devices as per approved drawing.

19.

Check proper operation of auxiliary devices as follows:

a.

b.

c. d. e. f.

Cooling fans/pumps (for all settings). Tap changer (upper–lower–out of step and interlock). Oil level gauges. Top oil temperature gauges. Buchholz relay by gas injection. Winding temperature gauges.

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g.

h.

i. j.

k. l.

OLTC oil/gas surge (pressure) relay. Ensure correct operation of the Pressure Relief Device microswitch. Push buttons and indicators. Oil sampling port (main tank and OLTC). Upper and lower main tank valves. Tap changer diverter switch compartment, oil filtering pumps and filter in good condition (if available).

20. Check oil leakage; if any noted, apply 0.35 kPa over pressure for 24 hrs to make sure.

21. Check that the oil sampling valves for the main tank and OLTC are accessible from ground level.

22. Check oil level in main tank, conservator, tap changer tank and bushings, etc. Test the oil level gauges and their alarms.

23. Bleed trapped air at the bushing turrets and radiators.

24. Check flow of oil in flow meter in correct direction and proper rate (if applicable).

26. Check all external wiring for correctness and tightness.

27. Check on-line insulating oil dissolved gas and moisture monitoring system (if installed).

1.2 Electrical Tests


1. Core Insulation Resistance Test.

2. Winding Insulation Resistance Test and Polarization Index Test at 5 kV DC.

3. Winding Resistance Test (all taps).

4.

Excitation Current measurements from primary side at each tap during ratio test and from secondary side when energized from secondary terminals keeping primary side open or winding excitation current measurement test at 10 kV during power factor testing.

5. Insulation power factor and bushing test at 10 kV AC.

6. Vector Relationship Test.

7.

Winding temperature device test by heating the sensor in oil bath and checking against standard thermometer. Also check by current injection. Setting as per approved drawing to be applied and tested.

8. Oil temperature device to be calibrated by heating in oil bath. Setting as per approved drawing to be

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applied and tested. 9. Percent Impedance test at nominal tap. 10. Turn Ratio (all taps).

11

Check for current and voltage ratings of all motors for tap changer and fans match to SEC standard supply. Check that MCBs for protection are set at proper over load settings.

12. Fan motor currents shall be measured and checked against rating. Check wiring size is adequate to carry the current.

13. Check that the phase sequence of supply voltage to fan motors is correct. Check fan rotation direction and confirm air flow is towards radiator.

14. MCBs in cooler control cubicle to be checked by current injection for alarm and trip.

15.

On load Tap Changer tests: a. Check current and voltage ratings

of tap changer motor. b. Raise/Lower Control (local–

remote) and indication, and perform adjustment as required.

c. End of tap travel control. d. End of winding travel control (both

ends). e. AVR setting of bandwidth, mid

point, time delay, etc., and adjust as per approved setting.

f. Master/Slave check out of step blocking alarm.

g. Master/Slave control check either transformer as master.

h. Parallel Operation Disturbed–check alarm.

i. Check that the windings are not open circuited during tap changing. This should be done during the winding resistance test.

16.

Bushing Current Transformer Tests: a. Polarity. b. Insulation Resistance. c. Secondary Winding Resistance (all

windings and all taps). d. Current Ratio (inject current) e. Magnetization Characteristics

(minimum five points below and two points above the knee point).

f. Verify secondary circuits, terminal to terminal.

g. Burden Test. Demagnetize CT cores after all tests. Ensure no open circuit on CT secondary side.

17 Functional Checks for the Following: a. Liquid level (alarm and trip).

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b. Top Oil Temperature Device: fans/pumps (stop, start alarm and trip).

c. Winding Temperature Device. d. Buchholz Relay (alarm and trip). e. Oil / Gas Surge (pressure) relay

(alarm and trip). f. Pressure Relief Device (alarm and

trip)

18.

Insulating Oil Tests: Prior to energization, the contractor shall submit insulating oil test reports tested at an independent laboratory, for the following:

a. Dielectric Strength i. ASTM D 877 (2.5 mm gap) for

unprocessed oil and for OLTC oil ii. ASTM D 1816 (1.0 mm gap) for oil

in main tank b. Neutralization Number (ASTM D 974) c. Interfacial Tension (ASTM D 971) d. Color (ASTM D 1500) e. Moisture Content (ASTM D 1533) f. Power Factor Test (ASTM D 924) g. Dissolved Gas in Oil Analysis (ASTM D3

612) h. (Dielectric Dissipation Factor, Resistivity,

Sediment and/or Precipitable Sludge). Another oil sample shall be given to SEC transmission for their own analysis and comparison purposes. A syringe oil sample shall be taken by contractor.

19.

A main tank insulation oil sample for dissolved gas analysis shall be taken immediately prior to first energizing a power transformer and another sample three days after continuous energization.

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2.0 Shunt Reactors (Standard Reference is IEC 60076 and relevant SEC Transmission Specifications)



1. Check the impact recorder for any abnormal impact during transit.

2. Check all components are installed.

3. Check for quality of paint, lifting lugs, quality of weld areas, rust spots and wheel stoppers.

4. Check nameplates information (visible location) as per contract specifications.

5. Check tightness of all bolts (torque wrench method).

6. Check that all grounding is securely connected (two grounding connections to main tank are required).

7. Check that the piping to Buchholz relay has proper slope. 8. Check that the tank pressure is positive, if applicable.

9. Check that the valves between the main tank and radiators are open.

10. Check the bushings for any damage and completeness.

11. Check for correct color and quantity of desiccant (moisture absorbing media) in breather. Check for correct breather oil level.

12. Check heaters and humidity meters in local panel are at correct settings.

13. Check that phase marking in cable box matches with GIS and cables.

14. Check all pipes, hoses and fan protection (not rubber or plastic).

15. Check the vertical and horizontal clearances of live parts to adjacent grounded points conform to standard.

16. Check integrity of diaphragm/air bag in the conservator. 17. Perform all of the manufacturer’s specific checks.

18. Check labeling of all auxiliary devices as per approved drawing.

19.

Check proper operation of auxiliary devices as follows: a. Cooling fans/pumps (for all settings). b. Oil level gauges. c. Top oil temperature gauges. d. Buchholz relay by gas injection. e. Winding temperature gauges. f. Ensure correct operation of the

Pressure Relief Device microswitch. g. Push buttons and indicators. h. Oil sampling port (main tank). i. Upper and lower main tank valves.

20. Check oil leakage; if any noted, apply 0.35 kPa over pressure for 24 hrs to make sure.

21. Check that the oil sampling valves for the main tank are accessible from ground level.

22. Check oil level in main tank, conservator and bushings, etc. Test the oil level gauges and their alarms.

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23. Bleed trapped air at the bushing turrets and radiators. 24. Check all external wiring for correctness and tightness.



1. Core Insulation Resistance Test

2. Winding Insulation Resistance Measurement Test and Polarization Index (P.I.) Test at 5 kV DC.

3. Winding Resistance Test. 4. Inductance Measurement. 5. Impedance Measurement.

6.

Winding temperature device test by heating the sensor in oil bath and checking against standard thermometer. Also check by current injection. Setting as per approved drawing to be applied and tested.

7. Oil temperature device to be calibrated by heating in oil bath. Setting as per approved drawing to be applied and tested.

8. Insulation power factor and bushing test at 10 kV AC.

9.

Bushing Current Transformer Tests: a. Polarity. b. Insulation Resistance. c. Secondary Winding Resistance (all windings

and all taps). d. Current Ratio (inject current) e. Magnetization Characteristics (minimum five

points below and two points above the knee point).

f. Verify secondary circuits, terminal to terminal. g. Burden Test.

Demagnetize CT cores after all tests. Ensure no open circuit on CT secondary side.

10.

Functional Checks for the Following: a. Liquid level (alarm and trip). b. Top Oil Temperature Device: fans/pumps

(stop, start alarm and trip). c. Winding Temperature Device. d. Buchholz Relay (alarm and trip). e. Pressure Relief Device (alarm and trip)

11.

Insulating Oil Tests: Prior to energization, the contractor should submit insulating oil test reports tested at an independent laboratory, for the following:

a. Dielectric Strength i. ASTM D 877 (2.5 mm gap) for unprocessed oil ii. ASTM D 1816 (1.0 mm gap) for oil in main

tank b. Neutralization Number (ASTM D 974) c. Interfacial Tension (ASTM D 971) d. Color (ASTM D 1500) e. Moisture Content (ASTM D 1533) f. Power Factor Test (ASTM D 924)

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g. Dissolved Gas in Oil Analysis (ASTM D3 612) h. (Dielectric Dissipation Factor, Resistivity, Sediment

and/or Precipitable Sludge). Another oil sample shall be given to SEC transmission for their own analysis and comparison purposes. A syringe oil sample shall be taken by contractor.

12. Cooling system checks and measure for fan motors and pumps (as applicable), etc., for current, supply voltage and air flow direction.

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3.0 Bushings Inspection and Testing (Standard Reference is IEC 60137 and relevant SEC Transmission Specifications)


1. Cleaning the insulator surface. 2. Check for tightness test between transformer and bushing

flange and outer terminal.

3. Visually inspect for any damage or cracks. 4. Check for leakage. 5. Check and adjust of oil level. Note that adding insulating oil to a

bushing shall be done under vacuum.

6. Measurement of capacitance and tan delta. The bushing shall be tested in a vertical position and the lower portion set into an oil reservoir.

7. Check of through resistance.

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4.0 Surge Arrestors (Standard Reference is relevant SEC Transmission Specifications)

4.1 Mechanical Checks and Visual Inspection:


1. Inspect for physical damage or defects. 2. Check tightness of all bolted connections (torque wrench

method).

3. For multi-unit stacks, check that the physical arrangement of the units are erected according to the manufacturer’s specifications.

4. Check that all grounding cables are correctly and secured connected.

5. Check name plate information for correctness as per SEC’s specifications.

6. Check that impulse counter and leakage current meter glasses are not broken or cracked.



1. Check calibration of leakage current meters. 2. Insulation resistance test at 5 kV DC. 3. Power factor test at 10 kV AC.

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5.0 Station Service Transformers (less than 2 MVA) (Standard Reference is relevant SEC Transmission Specifications)

5.1 Mechanical Checks and Visual Inspection


1. Check the Impact recorder for any abnormal impacts during transit (if applicable).

2. Check earthing, color, painting, external damage, oil leakage, wheel stopper, cable connection and bolt tightness, etc.

3. Check nameplate data against contract specifications. 4. Perform all special checks according to the manufacturer’s

instructions.

5. Check oil level in HV side cable box and its oil level indicator or HV fuses.

6. Check all devices are labeled correctly as per drawing.


ITEM DESCRIPTION DONE REMARKS 1. Check LV side MCB setting as per transformer current rating

2. Ratio Test (all taps), Insulation resistance measurement test on all windings and polarization index (P.I.) test.

3. Polarity and Vector Group symbols confirmation Test. 4. Check oil level and its indicator alarms. 5. Check oil temperature gauge by oil bath method and its alarms.

6. Check LV and HV side phases match with the LV bus bar phasing in the distribution panels and with the main transformer phases.

7. Check phasing at the automatic transfer switch (as applicable ) 8. Winding resistance measurement (at all taps). 9. Excitation current test (all taps).

10. Back energization test at rated voltage for 15 minutes.

11. Check that the off load tap changer is set at the nominal voltage tap.

12. Perform functional tests of all auxiliary devices (as applicable )

13.

Insulating Oil Tests: Prior to energization, the contractor should submit insulating oil test reports tested at an independent laboratory, for the following:

. Dielectric Strength i. ASTM D 877 (2.5 mm gap) for unprocessed oil ii. ASTM D 1816 (1.0 mm gap) for oil in main

tank b. Neutralization Number (ASTM D 974) c. Interfacial Tension (ASTM D 971) d. Color (ASTM D 1500) e. Moisture Content (ASTM D 1533) f. Power Factor Test (ASTM D 924) g. Dissolved Gas in Oil Analysis (ASTM D3 612) h. (Dielectric Dissipation Factor, Resistivity, Sediment

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and/or Precipitable Sludge). Another oil sample shall be given to SEC transmission for their own analysis and comparison purposes. . A syringe oil sample shall be taken by contractor.

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6.0 Neutral Earthing Resistors (Standard Reference is Manufacturer’s Instructions)


1. Check the value of resistance and current ratings against specifications.

2. Check that the external earth connection to main earth is copper wire at least 240 mm2 in size.

3. Test NER HV side associated CT and power cable. 4. Visually inspect the interior for broken insulators. 5. Measure the main circuit resistance. 6. Insulation Resistance Test. >=1000 megaohms 7. Ensure that the interior and exterior of the NER is clean prior to

energization.

8. Check identification and function of NER isolator (if applicable).

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7.0 Current Transformers (Standard Reference is IEC 60044-1 and relevant SEC Transmission Specifications) Note that Bushing current transformer tests and inspections are covered in the sections relating to the equipment into which they are installed.



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check that outdoor secondary wiring terminations are installed

in moisture proof enclosures.

4. Check tightness of all bolted connections (torque wrench method).

5. Check that all grounding cables are securely connected. 6. Check secondary wiring is correctly color coded and size of

wires is as specified.

7. Check proper lugs have been used on terminations. 8. Check CT locations physically and secondary terminal labeling

has been done correctly.



1. Insulation resistance test. 2. Winding resistance measurement. 3. Polarity test or flick test with battery. 4. Ratio test by current primary injection. 5. Magnetizing current test (minimum two points above knee

point).

6. Loop resistance measurement test (burden test). 7. Phase identification test. 8. Verify secondary circuits, terminals, shorting/isolating links by

primary injection of CTs.

9. Insulation power factor test (live tank CTs-110 kV and above if applicable).

10. High voltage test: During normal HV tests on switchgear or GIS the CTs are included in the HV test. CT secondaries shall be shorted to ground and isolated from relays and meters.

11. Test intercore coupling for all bus differential CTs. 12. Demagnetize CT cores after all tests.

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8.0 Potential Transformers (Standard Reference is IEC 60044-2 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check tightness of all bolted connection. 4. Check that the HV connection does not transfer stress to the HV

terminal.

5. Check that all grounding cables are securely connected. 6. Check mechanical clearances and proper operation of all

isolation and grounding devices (as applicable).

7. Check integrity of primary fuses (if applicable). 8. Check insulation liquid level (if applicable). 9. Gas leakage check for GIS VTs.



1. Winding Resistance Test. 2. Insulation resistance tests HV TO G, LV TO G

and HV TO LV using a one kV insulation tester.

3. Ratio Test. 4. Polarity Test. 5. Primary and secondary fuses rating checks for

11 kV VTs and above (if applicable).

6. Ensure VT is included in switchgear and GIS high voltage test.

Test voltage is 1.5Uo (where Uo is φ-N voltage) for 1 minute For electromagnetic VTs, see Table 1.

7. Check VT HV neutral is solidly grounded. 8. Check electrical operation of all isolating and

grounding devices (if applicable).

9. Check phase sequence, for the final three-phase assembly.

10. Verify secondary circuits, terminal to terminal for correctness and tightness.

11. Loop resistance test and burden test. 12. Check gaps of protective flashover devices (if

applicable).

13. Insulation power factor test, 110 kV and above. 14. Back energization test at rated voltage for 15

minutes.

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TABLE 1

SYSTEM RATED

VOLTAGE (KV)

RATED LOAD

FACTOR

TEST VOLTAGE

(KV) FREQUENCY TIME PERIOD

DONE

REMARKS

11 1.5 9.5 13.8 1.5 12 33 1.5 28 69 1.5 60

110 1.5 95 115 1.5 99.5 132 1.5 114 230 1.5 199 380 1.5 329

60 Hz

I Minute

These tests are applicable

to electromagneti

c VT’s

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9.0 Capacitive Voltage Transformers (Standard Reference is IEC 60044-5 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check tightness of all bolted connections. 4. Check that all grounding cables are securely connected. 5. Check mechanical clearances and proper operation of all

isolation and grounding devices (as applicable).

6. Check oil level (if applicable). 7. Check for oil leakage. 8. Check electromagnetic unit spark gaps for correct setting (if

applicable).

9. Check drain coils (if applicable).


ITEM DESCRIPTION DONE REMARKS 1. Winding Resistance Test. 2. Insulation resistance tests HV TO G, LV TO G and HV TO LV

using a one kV insulation tester.

3. Ratio Test. 4. Polarity Test. 5. Check HV neutral is solidly grounded. 6. Check electrical operation of all isolating and grounding devices

(if applicable).

7. Check phase sequence, for the final three-phase assembly. 8. Loop resistance and burden tests. 9. Capacitance and dissipation factor measurement tests.

10. Insulation power factor test, 110 kV and above. 11. Check on fast damping device (FDD).

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10.0 Coupling Capacitor Voltage Transformer (Standard Reference is IEC 60044-5 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check tightness of all bolted connections. 4. Check that all grounding cables are securely connected. 5. Check mechanical clearances and proper operation of all

isolating, grounding and shorting devices (as applicable).

6. Check electromagnetic unit spark gaps for correct setting (if applicable).

7. Check drain coil unit spark gaps for correct setting (if applicable).

8. Check wave trap mechanical assembly, bird screens, etc.


ITEM DESCRIPTION DONE REMARKS 1. Winding resistance test 2. Insulation resistance tests HV TO G, LV TO G and HV TO LV

using a one kV insulation tester.

3. Ratio test 4. Polarity test 5. Check electrical operation of all isolating and grounding devices

(if applicable)

6. Check phase sequence, for the final three-phase assembly. 7. Loop resistance and burden tests. 8. Capacitance and dissipation factor measurement tests. 9. Insulation power factor test, 110 kV and above.

10. Perform all specific tests per manufacturer’s instruction 11. Phase angle check if the equipment is assembled at site.

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11.0 Gas Insulated Switchgear (GIS) (Standard Reference is IEC 62271-203 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Inspect enclosures for proper alignment and

foundation fixing and grounding.

4. Check quality of paintwork. 5. Ensure that all special tools and equipment are

provided as specified and have proper storage.

6. Ensure that gas-handling cart (if provided) operates correctly and that special filling and degassing fittings are provided and have proper storage.

7. Verify that all lifting devices are correctly labeled for lifting capability.

8. Ensure that adequate ladders and walkways are provided for access to meters, filling ports, cranes, lights, etc.

9. Check and verify that all grounding of GIS is as per approved layout drawings and specification and is securely connected.

10. Check that all specified grounding switches are insulated, with removable grounding links.

11. Check operation of all mechanical interlocks. 12. Check tightness of all bolted connections (torque

wrench method).

13. Check each gas section filled to correct rated pressure.

14. Check SF6 gas at each gas section for air and moisture content after filling at rated pressure.

Permissible Dew Point is -35 °C or lower.

15. Gas leak test of all flanges and joints after erection and filling.

Wrap all joints with sealed plastic sheeting and test for gas leakage after 24 hours.

16. Calibrate gas pressure (density) gauges. Check the gauges have correct, legible and readable scales.

17. Check the gauges are ambient temperature compensated.

18. Check operation of all gas density switches (alarm trip signals and lockout functions). Confirm correct set points.

19. Check all wiring is correct according to approved drawings or confirm the correctness of all modifications.

20. Verify that all front panel mounted devices (meters, push buttons, switches, indicator lamps, mimic buses,

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etc.) are installed as per drawings, fixed permanently and are correctly labeled.

21. Verify that all operating devices are correctly labeled. 22. Perform mechanical checks and visual inspections on

all component equipment: a. Circuit breakers. b. Current transformers. c. Voltage transformers. d. Disconnect and grounding

switches.

23. Check that all phase marking and circuit labeling have been installed as per specifications.

24. Ensure that all disconnect switches are provided with viewing windows or mechanical indicators for verification of contact positions and that all grounding switch positions can be visually verified.

25. Verify that correct Dispatch Numbers have been installed.

27. Check the closed barriers at the ends of each gas zones are externally colored yellow or orange. The zone gas density gauges shall have a zone marking plates fixed over the gauges.

28. Check GIS over pressure relief discs are not cracked or deformed.



1. Insulation resistance test for all low voltage wiring and cabling.

2. Functional test of all controls and interlocks. 3. Resistance of all ground connection joints at 100 A

DC.

4. Resistance of bus joints at 100 amperes DC. 5. Overall resistance of the main circuit. Not more than 1.2 X

Rdesign with components (CBs, disconnects, etc.) in closed position.

6. Functional check of all alarms, interlocking and indication circuits from the switchgear through to the local control cubicle.

7. CB Timing Test (open and close) with contact travel and speed analysis.

8. Disconnect switch close and open time tests for the confirmation of early make and late break operation of auxiliary contacts with main contacts for CT switching schemes.

9. Checks on CB hydraulic system or vacuum system for pump start stop trip/close lockout threshold values.

10. GIS PTs to be included during AC HV tests on GIS when test frequency is well above rated frequency,

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otherwise test at 1.5Un – one minute at rated frequency without secondary load. PT secondary output volts shall be monitored during the high voltage test.

11. All AC/DC MCBS shall be tested by trip test through current injection.

12. Check and confirm GIS PTs primary isolation device with manual operation provided where fitted, along with it’s monitoring system locally as well as on mimic diagram in control room. Check VT HV neutrals externally available especially in case of VTS installed directly on cable feeder.

13. Check and confirm that the three-phase test adaptor and bushing for HV test on GIS has been provided.

14. Verify the alarms being initiated by SF6 density gauges on LCC and up to control room during calibration process.

15. Check that all cubicle space heaters and thermostats are functional and at correct temperature control settings.

16. Perform all electrical tests on following GIS components as per manufacturer’s instructions and SEC approved procedures.

Circuit breakers. Current transformers. Voltage transformers. Disconnect and grounding switches.

17. Perform high voltage test at 10 kV AC for 1 minute on all grounding switches’ external insulating bushings.

I. HV Tests on GIS Main Circuits AC HV tests on main circuit of GIS are performed with all CB’s and disconnect switches in the closed position at 80% of the factory routine test voltage for one minute. Partial discharge measurements (If applicable and possible to be performed) are performed at 1.2 X Un (Un = phase to neutral voltage). II. Preparation for HV Tests Check and confirm following points and condition to be met before high voltage tests.

i. The Switchgear shall be erected completely and filled with gas at rated pressure. ii. Some part may be disconnected before test, such as:

High Voltage cables and overhead lines. Power transformer and most voltage transformers. Surge arrestors and protective spark gaps. Current transformer secondary windings should be shorted and grounded.

iii. Every newly erected part of GIS shall be tested with high voltage. iv. The test should be performed at rated frequency (60 Hz.). If such arrangement is not

possible, then the frequency should be limited to the range of 30 to 300 Hz. v. AC voltage tests are sensitive in detecting contamination and abnormal field configuration. vi. Tests with switching impulse voltages are useful especially for high rated voltage to detect the

presence of contamination as well as abnormal field configuration

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III. Two Test Procedures are Utilized to Test the GIS Contractor can adopt one of the two procedures A or B to perform high voltage test on GIS after erection at site

i. Procedure A

Site AC test voltage level shall be equal to the 80% of the factory routine test voltage. This test may be performed through series resonance method Or by a test transformer with sufficient capacity. PD measurements are possible to be measured in

this case at test voltage level = 1.2 Un (Un = phase to neutral rated voltage) during the HV Test process.

Electrical conditioning at voltage equal to U/√3 for longer period such as 30 minutes may be performed to move and trap the contamination in areas where they become harmless.

Partial discharge measurements may be helpful in detecting some kind of faults.

ii. Procedure (B)

a. Through GIS Voltage Transformers

Site AC test voltage level equal to 1.2 Un for 5 minutes followed by Impulse Voltage test at a test level equal to 64% of the rated lightening impulse withstand level specified in IEC-517. Three positive and three negative polarity impulses shall be applied. b. With Separate Source In case the GIS VTs are not suitable to be used as test transformer; a special voltage transformer shall be used to perform such tests. GIS VT can only be used as a test transformer if the manufacturer guarantees its safety and capability to perform such tests otherwise it shall not be used as a test source.

IV. Deviation Due to Practical Needs Sometime in extension projects due to practical and technical reason of joining new and old GIS together, the test may be performed at reduced voltage level for an extended duration subject to agreement between SEC and supplier. V. Assessment of Tests

i. Test is considered passed if no disruptive discharge occurs during the test period. ii. If disruptive discharge occurs in solid insulation, the compartment should be opened and

repaired. After fault repair, again, test with full site test voltage. iii. If disruptive discharge occurs in gas, the test may be repeated and if discharge again takes

place, then compartment should be opened to clean out the compartment. iv. If the discharge occurs and second time it disappears, it should be considered acceptable

after repeating one test more at full site test voltage mentioned in Table 1. VI. Repetition of test after flash over at site Test may be repeated several times to listen and locate the location of fault point subject to the agreement between SEC and Contractor.

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Table-1 on the next page describes the exact test voltage levels, time and kind of tests to be applied after erection of GIS at site.

i. For 132 kV GIS the test voltage shall be 220 kV AC 60 Hz for one minute as per Procedure A clause 7.107.1.5 of IEC 517- 1990

ii. For 380 kV GIS and GIBs shall be 416 kV AC 60 Hz for one minute as per procedure A

clause 7.107.1.5 of IEC 517-1990. iii. In case of procedure B as per clause 7.107.1.5 of IEC 517-1990 the test voltage for 132 kV

rated GIS shall be 84 kV AC for 5 minutes and followed by 416 kV Impulses of three positive and three negative polarities.

iv. In case of procedure B to be applied for high voltage tests on 132 kV GIS special VT should

be used as Test voltage source. GIS VTs shall not be used as HV test voltage source.

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Table 1. Test Voltage Levels for Metal-Enclosed Gas Filled Switchgear (GIS)

Met

hod

No.

Sys

tem

Rat

ed

Vol

tage

K

V

Ele

ctric

al

Con

ditio

ning

AC

Tes

t V

olta

ge

kV

Freq

. O

f Tes

t V

olta

ge

Tim

e O

f A

C T

est

Vol

tage

Sw

ing

or

Sw

itchi

ng.

Impu

lse

leve

l

No.

Of

Impu

lses

Par

tial

Dis

char

ge

Mea

sure

RE

MA

RK

S

A 13.8 10 kV for 10 min. 30 60 Hz 1 min. - - -

Leakage current < 1000

mA

A 33 22 kV for 15 min. 56 60 Hz 1 min. - - -

Leakage current < 0.86

mA

A 69 44 kV for 30 min. 128

60 Hz. or 10-

300 Hz. 1 min. - -

At 48 kV less than

10 pC

Electrical conditioni

ng is a cleaning process

only.

B 69 - 44 60 Hz. 5 min. 248 kV

3 positive

3 negative

A 110 84 kV for 30 min. 220

60 Hz. or 10-

300 Hz. 1 min. - -

At 92 kV less than

10 pC



only.

B 110 - 84 60 Hz. 5 min. 416 kV

3 positive

3 negative

A 115 84 kV for 30 min. 220

60 Hz. or 10-

300 Hz. 1 min. - -

At 92 kV less than

10 pC



only.

B 115 - 84 60 Hz. 5 min. 416 kV

3 positive

3 negative

A 132 84 kV for 30 min. 220

60 Hz. or 10-

300 Hz. 1 min. - -

At 92 kV less than

10 pC



only.

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B 132 - 84 60 Hz. 5 min. 416 kV

3 positive

3 negative

A 230 142 kV for 30 min.

316

10-300 Hz.

Better 60 Hz.

1 min. - - -

B 230 - 142

10-300 Hz.

Better at 60 Hz.

5 min. 608 kV

3 positive

3 negative

A 380 245 kV for 30 min. 416

10-300 Hz.

Better at 60 Hz.

1 min. 840 kV

3 positive

3 negative

PD or HF detection

techniques to be

applied

Impulse test is

applied in

special cases only

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12.0 Metal Clad Switchgear (Standard Reference is IEC 62271-100 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Inspect enclosures for proper alignment, foundation fixing and

grounding and vermin proofing.

4. Inspect all covers, panels section and doors for paint work and proper fit.

5. Check for smooth and proper movement of racking mechanisms for alignment, shutters, rollers, rails and guides.

6. Check for proper alignment of the breaker primary and secondary contacts.

7. Check operation of all mechanical interlocks. 8. Check tightness of all bolted connections (torque wrench

method).

9. Check bus and supports for defects such as cracked welds, chipped porcelain, cracked insulation, etc., and free from dust accumulation.

10. Check main and riser buses for correct phasing. 11. Verify that all front panel mounted devices (meters, push

buttons, switches, indicator lamps, mimic buses, etc.) are installed as per drawings.

12. Perform mechanical checks and visual inspection on all circuit breakers.

13. Perform mechanical checks and visual inspection on all current transformers.

14. Perform mechanical checks and visual inspection on all voltage transformers.

15. Perform mechanical check and visual inspection on all disconnect and grounding switches.

16. Check for correct breaker position indication. 17. Check for correct spring status indication (spring

charged/discharged).

18. For air magnetic breakers check the arc chutes for damage and correct positioning above the interrupter contacts.

19. For minimum oil breakers, check correct oil level in each pole. 20. For SF6 breakers, check the correct gas pressure, quality and

leakage where possible.

21. For SF6 breakers, check the operation of the gas density switch (alarm and lockout functions).

22. Perform all specific checks on the breaker and spring operating mechanism according to the manufacture’s instructions.

23. Check that all control wiring is correct according to the approved drawing and terminal connections are secure.

24. Check all wiring is correct according to approved drawings. 25. Check that all phase marking have been installed per

specifications.

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27. Verify that correct Dispatch Numbers have been installed. 28. Check that all special tools, devices, etc., as per specification

have been provided.



1. Insulation resistance test of all circuits in the panels. 500 V DC 2. Functional test of all controls and interlocks. 3. Bus continuity and phasing test. 4. Main Circuit Resistance Test with the switchgear

erected but not yet connected to the cables. Performed with 10 or 100 Ampere DC by micro-ohmmeter from panel to panel on each phase from cable spouts with all circuit breakers racked in service and in the on position.

The resistance values from panel to panel should vary no more than 15%. Compare the measured resistance values with factory test results, and shall be within +/- 20% of factory test results.

5. Check all AC/DC MCBS in the panel for correct ratings and grading. Trip test by current injection for one point on curve.

6. Insulation resistance test at 5 kV DC on all main circuits between phase to phase and phase to ground (before HV test).

7. Perform electrical tests on all component equipment as per SEC approved procedures:

a. Circuit breakers. b. Current transformers. c. Voltage transformers. d. Disconnect and grounding switches.

Ensure the cable spouts are included in the high voltage tests.

8. Insulation test on all wiring at 500 V DC. 9. Functional test of all electrical interlocks.

10. Functional test of trip free and anti pump circuits. 11. Functional test of local alarm and indications. 12. Functional test of remote alarm and indications. 13. Minimum control voltage trip and close operations. 14. Check and test capacitor trip circuit (if applicable). 15. Check spring charge time and motor currents at rated

control voltage.

16. Functional check of thermostat and space heaters, measure heater current.

17. Functional check of breaker operation counter. 18. Timing test open/close using an electronic

oscillograph.

19. For SF6 breakers, verify electrically the low gas pressure alarm and lockout functions.

20. For minimum oil breakers, test insulating oil for dielectric strength according to ASTM D 877 (with 2.5 mm gap).

21. Check correct operation of all auxiliary “a” and “b” contacts (for breaker open/closed position).

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Guidelines for High Voltage Tests on main circuits including CBs

i. Preparation and precautions before HV Test ii. For vacuum breakers, test across open contact and live parts to ground. Precautions shall be

taken against emission of X-rays. iii. For all other breakers. Test in conjunction with breaker racked in the switchgear and in the

closed position. The following shall be observed: • New switchgear should be tested as a whole unit with all circuit breakers in the closed position and

not connected to cables. • All back shutters must be closed. • Gas circuit breaker interrupters should be checked to be within limits of correct pressure. • VTs, cables or any other voltage indication should be disconnected and VTs secondary side fuses

should be removed. • VTs, cables or any other voltage indication should be in out position and VTS secondary side fuses

should be taken out. • CTs secondary terminals should be short-circuited and earthed. • Test voltage should be applied on each phase to ground with other phases in earthed position. The

test should be repeated on other phases similarly. • The test period should not be more than one minute at full test level and the test voltage frequency

should be kept at 60 Hz. • Charging current for each test is noted and recorded. • HV Test is considered successful if no breakdown occurs during test period. • HV Test levels and time for pre-commissioning testing of switchgear are given in Table 2. II. AC High Voltage test The test program shall be: • Voltage shall be applied on each phase with all other phases and then frame grounded. • Tests shall be performed with the CB in both the closed and open position • In the open position, the cable contacts are to be grounded. • Test voltage levels are given in Table 2 below. • After the high voltage test on main circuit is finished, rack the voltage transformers in service

position and apply a test voltage on the primary side equal to 1.5Un (Un = phase to neutral rated voltage) on each phase consecutively and measure the secondary output voltage same time during the test.

• Make sure the VTs secondary side MCBs are switched off and any resistor in open delta winding should have been removed.

• Compare the observed ratio with actual ratio. • The HV Test should be repeated with circuit breakers in open position keeping cable spouts in

earthed condition in all panels.

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TABLE 2. TEST VOLTAGE LEVEL FOR MEDIUM VOLTAGE METALCLAD SWITCHGEAR

SWITCHGEAR RATINGS AC TEST VOLTAGE TIME PERIOD

11 kV 25 kV 60 Hz 60 Sec

13.8 kV 30 kV 60 Hz 60 Sec

33 and 34.5 kV 56 kV 60 Hz 60 Sec

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13.0 Metal Enclosed Bus Duct (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check bus arrangement for conformance with approved

drawings.


4. Check that all enclosure grounding is securely connected. 5. Inspect internal compartments for cleanliness (free from dust

and moisture).

6. Check for watertight seals at joints including expanding interface points.

7. Check bus conductor support insulators for cracked insulation, chipped porcelain, etc.

8. Check quality of paint work (inside and outside). 9. Check that ventilation opening are not blocked, and meet

specified Degree of Protection.

10. Moisture drain holes available at bottom of enclosure. 11. Check anti-condensation heaters mounted at the correct

locations (bottom)



1. Perform phasing checks. Ensure correct phase identification. 2. Perform continuity check. 3. Bus joint resistance test. Ductor at

100 A DC 4. Insulation resistance test 5. HV test (to ground and between phases). 6. Heaters and thermostats functional test. Measure the heater

currents.

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14.0 Indoor and Outdoor Bus Structures (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect bus and support insulators for physical damage or defects.

2. Check bus physical arrangement for conformance with approved drawings.

3. Check bus connections for correct phasing and marking of phases.


5. Check for proper phase to phase and phase to ground clearances.

6. Ensure that PT, etc., connections are flexible, to prevent transferring expansion stress from the bus



1. Measure resistance of bus section joints. Ductor at t 100 A DC.

2. Insulation resistance test at 5 kV DC. 3. HV test (indoor bus work including PTs where applicable, 69 kV

and below).

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15.0 Indoor Circuit Breakers (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect bus for physical damage or defects. 2. Check nameplate information for correctness. 3. Check tightness of all bolted connections (torque wrench

method).

4. Check all wiring is correct according to approved drawings and that terminal connections are secure.

5. Check quality of paintwork. 6. Check that all grounding cables are securely connected. 7. Check breaker truck, rails, for proper alignment and smooth

movement.

8. Check operation of all mechanical interlocks with associated disconnects, grounding switches, racking truck mechanism, cubicle doors, etc.

9. Check for correct breaker position indication (breaker open/closed).

10. For minimum oil circuit breakers, check for correct oil level in each pole.

11. For SF6 breakers: a. Check for correct SF6 pressure in each pole. b. Check for gas leakage. c. Calibrate SF6 pressure gauge. d. Check operation of gas density switch (alarm

and lockout functions). e. Verify that all special filling adapters have

been provided.

12. For motor/spring operation mechanisms: a. Check manual spring charge operation. b. Verify correct spring status indication (spring

charged/discharged). c. Perform all specific checks on the mechanism

according to the manufacture’s instructions.

13. For pneumatic operating mechanisms(69KV and above): a. Check the compressor, air piping, valves,

pressure gauges, air filter, water trap and switches for damage, defects or blockage.

b. Calibrate the air pressure gauges. c. Check the setting of air pressure switches

(compressor start/stop, alarm, lockout). d. Perform all specific checks on the

compressed air system according to the manufacturer’s instructions.

e. Check for correct direction of compressor rotation.

f. Check air-charging time. g. Check safety relief valve operating pressure

and resetting pressure.

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h. Measure air consumption for C, O, CO and OCO operations.

i. Air storage test, perform as specified, the following without replenishment: 5X CO, or O + CO + 3min. + CO

j. Air leakage test (pressure drop method over 24 hours, CB closed and open).

14. For hydraulic operating mechanisms: a. Check, the pump, piping, valves, gauges and

switches for damage/defects/blockage. b. Bleed air from hydraulic system. c. Calibrate the fluid pressure gauges. d. Check the Nitrogen pre-charge pressure in

accumulators. e. Check for correct hydraulic fluid level in the

reservoir. f. Check the setting of air pressure switches

(pump start/stop, alarm, lockout). g. Perform all specific checks on the hydraulic

system according to the manufacturer’s instructions.

h. Check for oil leaks i. Check pump-up time. j. Check safety relief valve operating and

resetting pressure. k. Measure pressure drop for C, O, CO and

OCO operations. l. Stored energy test – perform O + CO + 3min

+ CO without replenishment. m. Oil leakage test (pressure drop method over

24 hours, CB closed and open). n. Check operation of the nitrogen low pressure

switch.

15. Verify that correct Dispatch Numbers have been installed.


ITEM DESCRIPTION DONE REMARKS 1. Measure resistance of main conducting circuits at 100 A DC. 2. Insulation resistance test of each breaker pole at 5 kV DC. 3. Insulation resistance test of all low voltage wiring and cabling. 4. Functional test of all electrical interlocks. 5. Functional check of trip free and anti pump circuits. 6. Functional check of phase disagreement protection circuit

(applicable to breakers whose poles are not mechanically gang operated).

7. Functional check of local control, alarm and indications. 8. Functional check of remote control, alarm and indications. 9. Minimum control voltage trip and close operation.

10. Functional check of breaker operation counter. 11. Functional check of thermostat and space heaters, and

measurement of heater current.

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12. Check correct operation of all auxiliary “a” and “b” contacts (for breaker open/closed positions).

13. Timing test using an electronic oscillograph. 14. For SF6 breakers, verify electrically the low gas pressure alarm

and lockout functions.

15. For minimum oil circuit breakers, test insulating oil for dielectric strength.

ASTM D 877(with 2.5 mm gap)

16. For motor/spring operating mechanisms, measure spring charge time and motor current.

17. For pneumatic or hydraulic mechanisms: a. Measure compressor/pump motor starting and

running currents. b. Verify electrically the low stored energy (fluid

pressure) alarm and lockout functions. c. Functional check of the motor excessive

running alarm circuit.

18. Verify the electrical operation of the breaker racking truck. Check the correct functioning of interlocks and limit switches.

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16.0 Outdoor Circuit Breakers (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check tightness of all bolted connections (torque wrench

method).

4. Check all wiring is correct according to approved drawings and that terminal connections are secure.

5. Check quality of paintwork. 6. Check that all grounding cables are securely connected. 7. Check for correct breaker position indication (breaker

open/closed).

8. For SF6 breakers: a. Check for correct SF6 pressure in each pole. b. Check for gas leakage. c. Calibrate SF6 pressure gauge. d. Check operation of gas density switch (alarm

and lockout functions). e. Check air and moisture content of SF6 gas in

breaker.

9. For motor/spring operation mechanisms: a. b.

c.

Check manual spring charge operation. Verify correct spring status indication (spring charged/discharged). Perform all specific checks on the mechanism according to the manufacture’s instructions.

10. For pneumatic operating mechanisms: a.

b. c.

d.

e.

f. g.

h.

i.

j.

Check the compressor, air piping, valves, pressure gauges, air filter, water trap and switches for damage or defects. Calibrate the air pressure gauges. Check the setting of air pressure switches (compressor start/stop, alarm, lockout). Perform all specific checks on the compressed air system according to the manufacturer’s instructions. Check for correct direction of compressor rotation. Check air-charging time. Check safety relief valve operating pressure and resetting pressure. Measure air consumption for C, O, CO and OCO operations. Air storage test, perform as specified, the following without replenishment: 5X CO, or O + CO + 3min. + CO Air leakage test (pressure drop method over 24 hours, CB closed and open).

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11. For hydraulic operating mechanisms: a. Check, the pump, piping, valves, gauges and

switches for damage/defects. b. Calibrate the fluid pressure gauges. c. Check for correct hydraulic fluid level in the

reservoir. d. Check the setting of air pressure switches

(pump start/stop, alarm, lockout). e. Perform all specific checks on the hydraulic

system according to the manufacturer’s instructions.

f. Check for oil leaks g. Check pump-up time. h. Check safety relief valve operating and

resetting pressure. i. Measure pressure drop for C, O, CO and

OCO operations. j. Stored energy test – perform O + CO + 3min

+ CO without replenishment. k. Oil leakage test (pressure drop method over

24 hours, CB closed and open). l. Check operation of the nitrogen low pressure

switch.



1. Measure resistance of main conducting circuits at 100 A DC. 2. Insulation resistance test of each breakers pole at 5 kV DC. 3. Insulation resistance test of all low voltage wiring and cabling. 4. Functional test of all electrical interlocks. 5. Functional check of trip free and anti pump circuits. 6. Functional check of phase disagreement protection circuit

(applicable to breakers whose poles are not mechanically gang operated).

7. Functional check of local control, alarm and indications. 8. Functional check of remote control, alarm and indications. 9. Minimum control voltage trip and close operation.

10. Functional check of breaker operation counter. 11. Functional check of thermostat and space heaters, and

measurement of heater current.

12. Check correct operation of all auxiliary “a” and “b” contacts (for breaker open/closed positions).

13. Timing test using an electronic oscillograph. 14. For SF6 breakers, verify electrically the low gas pressure alarm

and lockout functions.

15. For minimum oil circuit breakers, test insulating oil for dielectric strength.

ASTM D 877 (with 2.5 mm gap)

16. For bulk oil breakers: a. Test insulating oil for dielectric strength and

water content.

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i. ASTM D 877 (with 2.5 mm gap) – for dielectric breakdown

ii. ASTM D 1533A – for water content.

b. Timing test using a time travel analyzer, measuring:

i. Contact stroke, wipe and simultaneity.

ii. Over travel and damping oscillations during closing.

iii. Close and opening speeds. iv. O, C, CO and OCO times.

17. For motor/spring operating mechanisms, measure spring charge time and motor current.

18. For pneumatic or hydraulic mechanisms: a. Measure compressor/pump motor starting and

running currents. b. Ensure that all air is bled from the hydraulic

system. c. Verify electrically the low stored energy (fluid

pressure) alarm and lockout functions. d. Functional check of the motor excessive

running time alarm circuit.

19. AC HV test (applicable to SF6 breakers, if the tank is opened at site, e.g., to install bushings.

20. Bushing current transformer test (applicable to dead tank breakers)

21. Insulation and bushing power factor tests.

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17.0 Disconnect and Grounding Switches (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check quality of galvanizing (if applicable). 4. Check tightness of all bolted connections (torque wrench

method).

5. Check smoothness and ease of operation (both closing and opening).

6. Check simultaneity and synchronism of all 3 poles during closing.

7. Check for proper contact, fingers spread and contact pressure in fully closed position.

8. Check that end of travel stops are correctly adjusted, set and locked in position.

9. Check open gap and minimum clearance between phases and to ground

10. Check switch opens more than 90° (for horizontally mounted vertical open disconnects).

11. Check switch drive linking toggled in both the closed and opened positions.

12. Check that switch can be pad locked in both the closed and opened positions.

13. Check that all grounding is securely connected. 14. Check that switch-operating handle is grounded properly as

specified.

15. Check mechanical interlocks (with grounding switches, CBs, etc.).

16. Check that the operator’s platform is of adequate size and is properly grounded.



1. Measure resistance of main current path (terminal to terminal) at 100 A DC.

2. Functional test of all electrical interlocks. 3. Check position-signaling contacts (if applicable). 4. For motor operated mechanisms:

a. Check mechanism cabinet is grounded.

b. Check correct setting of motor limit switched (open/close).

c. Check correct operation of all auxiliary “a” and “b” contacts.

d. Measure switch opening and closing times and motor current at

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rated voltage (for fast acting disconnects and grounding switches, perform a timing test with an electronic oscillograph).

e. Minimum voltage operation (close and open) at 90 V DC.

f. Functional check of thermostat and space heaters. Measure heater current.

g. Insulation test all control and power wiring/cables at 500 V DC/

h. Check that in the manual mode, insertion of the operating handle automatically disconnects the motor DC supply.

5. For bus bar isolators, carefully check make and make before brake contact function for auxiliary switch contacts used for CT switching schemes during open close time test on disconnect main contacts.

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18.0 Circuit Switchers (Standard Reference is relevant SEC Transmission Specifications)



1. Perform mechanical checks and inspection of isolating disconnect, as per Section 3.17.1, above.

2. Perform mechanical checks and adjustments on interrupter unit according to the manufacturer’s instructions.

3. Check the low SF6 target at the interrupter units. 4. Check interrupter position indicator operation.


ITEM DESCRIPTION DONE REMARKS 1. Resistance of main current path (terminal to

terminal) at 100 Amps DC.

2. Functional check of all electrical interlocks. 3. Check position-signaling contacts (if applicable). 4. For motor operating mechanisms:

a. Check mechanism cabinet properly grounded.

b. Check correct setting of motor limit switched (open/close).

c. Check correct operation of all auxiliary “a” and “b” contacts.

d. Measure switch opening and closing times and motor current at rated voltage (for fast acting disconnects and grounding switches, perform a timing test with an electronic oscillograph).

e. Minimum voltage operation (close and open) at 90V DC.

f. Functional check of thermostat and space heaters. Measure heater current.

g. Insulation test all control and power wiring/cables at 500V DC

h. Check that in the manual mode, insertion of the operating handle automatically disconnects the motor DC supply.

5. Check shunt trip device operation. 6. Verify proper operation sequence of interrupters

and disconnects.

7. Insulation power factor test of the interrupters. 8. Timing test of the interrupter contacts with electronic

oscillograph.

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19.0 LV Switchgear (110/220 V) (Standard Reference is IEC 60947-2 and relevant SEC Transmission Specifications)

19.1 Inspections and Tests


1. Main circuits Continuity Test for tightness of joints and bolts.

2. Main circuit insulation resistance measurement by 2.5 kV Megger or 2 kV AC HV test for one minute.

3. Phasing check. 4. Check and verify for all MCCBs ratings as per

requirement and Trip Test by current injection.

5. All ammeters and volt meters shall be calibrated. 6. Insulation Test on all secondary wiring and

cables.

7. Tests on changeover schemes as per approved drawings if applicable.

8. Confirm the neutral cable coming from auxiliary transformer is grounded in the LV distribution board.

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20.0 230 kV and 380 kV XLPE Cables (Standard Reference is IEC 60287 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check tightness of all bolted connections (torque

wrench method).

3. Check for proper cable bolted connections. 4. Check for proper cable support, clamping, trays,

blocking.

5. Check cable bends to ensure that bending radius is equal to or greater than the minimum bending radius specified.

6. Link box tightness check. 7. Verify that shields are terminated as specified

(through link box or directly grounded).

8. Verification of exact route length from termination to termination as per approved drawings.

9. Check that all grounding points are securely connected to ground grid as specified.

10. Check that phases are identified and color coded. 11. Single core cable connected between power

transformer and switchgear shall be single point earthed at switchgear side and at floating side SVL (sheath voltage limiter) should be installed.

12. Check single point or both ends, via voltage limiter as per approved design.

13. Check cable entry path trench as ducts are to be properly sealed.

14. For accessories (sealing terminations, instrument panels and link boxes), check the following as applicable:

a. Nameplates installed and data is correct.

b. Condition of paint work. c. All bolted connections.



1. Phase checking for conductor and sheath bonding in every link box.

2. Conductor resistance, capacitance and inductance measurement test.

3. Sheath DC high voltage test (10 kV for 1 minute) and 5 kV DC insulation tester before and after high voltage test.

4. Anti corrosion sheath test. 5. Measure the ground resistance at all link box less than 10 Ω

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positions. 6. Zero and positive sequence impedance

measurement.

7. SVL (sheath voltage limiter) test with 2.5 kV DC insulation tester.

8. Insulation resistance test of cable by 5 kV DC. 9. Cross – bonding verification test. Sheath Current < 3 % 10. Contact resistance test on link boxes (less than

20 µΩ).

11. Metallic sheath continuity test (if applicable). 12. Cable jacket test. 13. Cable profile test. 14. AC High voltage test. See table 2-1

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21.0 230 kV and 380 kV LPOF Cables (Standard Reference is IEC 60141-1 and relevant SEC Transmission Specifications)




wrench method).

3. Check for proper cable bolted connections. 4. Check cable bends to ensure that bending radius is

equal to or greater than the minimum bending radius specified.

5. Check for proper cable support, clamping, trays and blocking.

6. Verify that shields are terminated as specified (through link box or directly grounded).

7. Verification of exact route length as per approved drawings from termination to termination.


9. Pressure test of all associated oil piping. 10. Check that phases are identified and color coded. 11. Single core cable connected between power


12. Availability of oil sampling facility valve arrangement. 13. Check single point or both ends, via voltage limiter

as per approved design.


15. Oil flow test. 16. Impregnation test. 17. RGP test and DGA tests. 18. For accessories (sealing terminations, pressure

tank, gauges, instrument panels and link boxes), cheek the following as applicable:


b. All valve positions according to design (open/closed).

c. Calibrate pressure gauges and pressure switches.

d. Oil pressure. e. No oil leaks. f. Condition of paint work. g. All bolted connections.

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1. Check Phasing for conductor and sheath bonding in every link box


3. Sheath DC high voltage test (10 kV for 1 minute) and 5 kV DC insulation tester before and after high voltage.

4. SVL (surge voltage limiter)test by 2.5 kV DC insulation tester.

5. Anti corrosion sheath test. 6. Measure the ground resistance at all link box

positions (less than 10 Ω).

7. Zero and positive sequence impedance measurement.

8. Insulation resistance test for conductor. 9. Cross – bonding verification test. Sheath current <3% 10. Contact resistance test on link boxes. less than 20 µΩ 11. Oil pressure gauge function test. 12. Shield continuity test. 13. Cable Jacket test. 14. Cable profile test. 15. Insulation oil dielectric breakdown test and water

content test.

16. AC High voltage test. See table 2-1

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22.0 110 kV, 115 kV and 132 kV XLPE Cables (Standard Reference is IEC 60840 and relevant SEC Transmission Specifications)




wrench method).



5. Check for proper cable support, clamping, trays, blocking.








13. Inspection of label inside link boxes and water proofing test.


15. For accessories (sealing terminations, instrument panels and link boxes), cheek the following as applicable:


b. Condition of paint work c. All bolted connections



1. Check phasing for conductor and sheath bonding in every link box.

2. Sheath DC high voltage test and 5 kV DC insulation tester before and after high voltage test.

10 kV for 1 minute


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4. Conductor insulation resistance test. 5. Cross – bonding verification test. Sheath Current < 3 % 6. Zero and positive sequence impedance

measurement.

7. SVL (sheath/surge voltage limiter) test with 2.5 kV DC insulation tester.

8. Measure the ground resistance at all link box positions.

less than 10 Ω

9. Contact resistance test on link boxes. less than 20 µΩ 10. Metallic sheath continuity test (if applicable). 11. Cable Jacket test. 12. Cable profile test. 13. AC high voltage test. See table 2-1

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23.0 110 kV, 115 kV and 132 kV LPOF Cables (Standard Reference is IEC 60141-1, -2, -3 and relevant SEC Transmission Specifications)




wrench method).

3. Check for proper cable bolted connections. 4. Check for proper cable support, clamping ,trays,

blocking.

5. Check cable bends to ensure that bending radius is equal to or greater than the minimum bending radius specified.

6. Verify that shields are terminated as specified (through link box or directly grounded).



9. Pressure test of all associated oil piping. 10. Check that phases are identified and color coded. 11. Single core cable connected between power


12. Availability of oil sampling facility valve arrangement. 13. Check single point or both ends, via voltage limiter

as per approved design.

14. Oil flow test. 15. Impregnation test. 16. RGP test and DGA test. 17. Check cable entry path trench as ducts are to be

properly sealed.

18. For accessories (sealing terminations, pressure tank, gauges, instrument panels and link boxes), check the following as applicable:


b. All valve positions according to design (open/closed).

c. Calibrate pressure gauges and pressure switches.

d. Oil pressure. e. No oil leaks. f. Condition of paint work. g. All bolted connections.

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1. Check phasing for conductor and sheath bonding in every link box

2. Sheath DC high voltage test with 5 kV DC insulation test before and after high voltage test.

10 kV for 1 minute

3. Conductor resistance, capacitance and inductance measurement.

4. Conductor insulation resistance test. 5. Cross – bonding verification test. Sheath Current < 3 % 6. Link box tightness check. 7. SVL (sheath voltage limiter) test with 2.5 kV DC

insulation tester.

8. Inspection of label inside link boxes and water proofing test.

9. Measure the ground resistance at all link box positions.

less than 10 Ω

10. Contact resistance test on link boxes. 11. Oil pressure gauge function test. 12. Shield continuity test. 13. Cable Jacket test. 14. Cable profile test. 15. Insulation oil dielectric breakdown test and water

content test.

16. AC high voltage test. See table 2-1

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24.0 69 kV XLPE Power Cables (Standard Reference is IEC 60840 and relevant SEC Transmission Specifications)




wrench method).



5. Check for proper cable support, clamping, trays, blocking.









14. For accessories (sealing terminations, instrument panels and link boxes), cheek the following as applicable:


b. Condition of paint work. c. All bolted connections.



1. Check phasing for conductor and sheath bonding in every link box.


3. SVL (sheath voltage limiter) test with 2.5 kV DC insulation tester.

4. Anti corrosion sheath test. 5. Measure the ground resistance at all link box

positions. less than 10 Ω

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6. Zero and positive sequence impedance measurement.

7. Insulation resistance test for conductor. 8. Sheath DC high voltage test (10 kV for 1 minute)

and 5 kV DC insulation tester before and after high voltage test.

9. Cross – bonding verification test Sheath current < 3 % 10. Contact resistance test on link boxes. less than 20 µΩ 11. Metallic sheath continuity test (if applicable). 12. Cable Jacket test. 13. Cable profile test. 14. AC High voltage test. See table 2-1

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25.0 13.8 kV and 33 kV XLPE Power Cables (Standard Reference is IEC 60502 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. Check irregularities of outer jacket caused by non-uniform shield wire distribution.

2. Verify all cable connections as per drawing. 3. Check for proper cable support, clamping, trays, blocking. 4. Check cable bends to ensure that the bending radius is equal to

or greater than the minimum bending radius specified.

5. Verify shield grounding as per design (single point, both ends, via voltage limiters, etc.


7. Single core cable connected between power transformer and switchgear shall be single point earthed at switchgear side and at floating side SVL (sheath voltage limiter) should be installed.

8. Check that phases are identified and color coded. 9. Check cable entry path trench as ducts are to be properly

sealed.


11. Check for proper cable arrangement in the path (RYB) in order to prevent circulating current.



1. Sheath armor continuity test. 2. Sheath insulation resistance test. IR for sheath >

10 megohms 3. Main conductors insulation resistance test (5KV DC insulation

tester) before and after HV Test.

4. Phasing and continuity test of main conductor 5. AC- high voltage test

a. For new XLPE power cables, AC HV test voltages should be applied up to 2 Uo for one hour or by VLF at 0.1 Hz at test voltage level of 3 Uo for one hour can be performed.

b. For mixed new and old cables, the test voltage shall depend upon the service life of the old cable.

c. At least It should be tested at normal working voltage phase to neutral (Uo).

d. Mixed new and old cables should not be tested by DC test voltage at any condition except by AC or VLF methods.

e. Where cables are connected to switchgear, the AC HV test time should be reduced to 5

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minutes. One hour test applies if the cables are fully isolated.

f. Uo for all the applied tests is equal to phase to neutral voltage.

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26.0 LV Cables (Standard Reference is IEC 60227-2 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check for proper cable support, clamping, trays,

blocking.

3. Verify all cable connections as per approved drawing.

4. Verify that all cables and cores are labeled correctly.

5. Check tightness of terminals and confirm the cables are secured.

6. Check that all cable trays are secure and correctly grounded.


8. Visual Insulation, size and rating confirmation. 9. Check cable size against rating required.



1. Phasing and continuity check. 2. AC HV Test at 2 kV 60 Hz for 1 minute between

core to core and core to grounded armor.

3. Insulation Resistance Test with 2.5 kV DC insulation tester.

>=100 MΏ

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27.0 Control Cable (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage/defects. 2. Verify all cable connections as per approved drawing. 3. Verify that all cables and cores are labeled correctly. 4. Check for proper cable duct, support, clamping, trays, blocking. 5. Check tightness of terminals, ferrule numbering and confirm the

cables are secured.

6. Check that all cable trays are secure and correctly grounded. 7. Check all cables are securely supported throughout. 8. Visual inspection, size and rating confirmation. 9. Size checking against rating required.


ITEM DESCRIPTION DONE REMARKS 1. Phasing and continuity check. 2. Insulation Resistance Test with 1 kV DC insulation tester. IR > 100

Megohms

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28.0 Pilot Cables (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Verify all cable connections as per approved

drawing.

3. Verify that all cables and cores are labeled correctly.

4. Check for proper cable support, clamping, trays, blocking, etc.

5. Check tightness of terminals, ferrules, wiring identification and confirm the cables are secured.

6. Check that all cable trays are secure and correctly grounded.

7. Check all cables are securely supported throughout.

8. Visual inspection, size and rating confirmation. 9. Size checking against rating required. 10. Verification of exact route length as per approved

drawings from termination to termination.


ITEM DESCRIPTION DONE REMARKS 1. Conductor loop resistance test for all pairs. 2. Core Identification for each core between two

ends.

3. Insulation Resistance for sheath armor to ground by 500V DC insulation tester for each section before jointing.

IR > 10 megohms

4. Insulation Resistance for sheath armor to ground with a 500 V DC insulation tester after all joints are completed and before termination in the pilot boxes (if applicable).

IR > 10 megohms

5. Capacitance measurement for all cores. 6. Insulation resistance test between core to core

and core to ground with a 5 kV DC insulation tester.

IR > 1000 megohms

7. Frequency response test. 8. End to end terminal and pair matching. 9. Noise Level Measurement.

10. Cross-talk and coupling test between pairs. 11. High voltage test for protection and control core

by 15 kV DC for 1 minute.

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TEST VOLTAGE LEVELS FOR HIGH VOLTAGE POWER CABLES

SYSTEM RATED VOLTAGE (KV)

PRE-COMMISSIONING SITE TEST LEVEL

TIME PERIOD (MINUTES)

13.8 kV XLPE POWER CABLES

2Uo = 16 kV AC or

VLF test level = 3Uo = 24 kV

60

60

33 kV XLPE POWER CABLES

2Uo = 38 kV AC or


60

60

69 kV XLPE POWER CABLES

2Uo = 80 kV AC or


60

60 110/115 kV XLPE/LPOF

POWER CABLES 2Uo = 128 kV AC 60

132 kV XLPE/LPOF POWER CABLES 2Uo = 152 kV AC 60

230 kV XLPE/LPOF POWER CABLES 2Uo = 265 kV AC 60

380 kV XLPE/LPOF POWER CABLE 2Uo = 438 kV AC 60

REFERENCES

AC HV Test: Recommendation by KEMA Research Laboratory (Netherlands). VLF Test: Recommendation by High Voltage Corporation (USA) and Seba-Dynatronic (GERMANY) as a

Manufacturer of VLF Test Sets.

Test Voltage levels for LV Cables, Control Cable and Pilot Cables

SYSTEM RATED VOLTAGE (KV)

PRE-COMMISSIONING SITE TEST LEVEL

TIME PERIOD (MINUTES)

LV Cables 2.5 kV DC Insulation Tester 1

Pilot Cable Core to Core and Cores to Sheath Test

Protection and Control Core

- Insulation Resistance Test by 5 KV DC Insulation Tester IR > 1000 megohms

1

Pilot Cable Core to Core and Cores to Sheath Test

Protection and Control Core

If IR < 1000 megohms, perform the following test : 10 kV DC between core to core of the pairs and 15 kV DC between all cores to grounded armor

1

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29.0 Overhead Lines (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect that the access roads and structure pads are to specification (locations, widths, depth of base, cover material properly compacted, etc.).

2. Check that sand stabilization has been done per specification (if applicable).

3. Check the right of way to ensure that there is no construction or agricultural encroachment.

4. Check that the ground profile allows water run-off from the structures.

5. Check that grounding connection is made properly with steel structure and protective coating is applied on the concrete cap (if specified). There shall be no cracks, and the concrete cap shall slope away from the stub angle.

6. Check that crash barrier and/or flood protection are being done as per specification (if applicable).

7. For wooden pole structures, ensure that pole types and sizes are the correct specification and have been installed correctly (depth and plumb). Ensure that the depth indication tags are on each pole.

8. For wooden pole structures, check structure guy wire, cross braces, and other framing work have been done correctly.

9. Check that all wood structures have been identified correctly and that the identification plates are to specification. For double circuit structures, ensure that each circuit is correctly identified.

10. For steel structures, ensure that type is as per specification / drawings.

11. Check galvanizing quality and thickness (rust is not acceptable).

12. Check bolt types and tightness (torque wrench method). 13. Ensure anti-climbing guards are correctly installed (if

applicable).

14. Check step bolt tightness. 15. For porcelain insulators, check insulators for chips, cracks,

etc. Ensure correct number of insulators have been installed in each string. Ensure that cotter keys have been properly installed.

16. For composite insulators, perform close elevated inspection on each structure to check that the insulator sheaths and sheds are not cracked, damaged or torn. The inner fiberglass rod should not be exposed at any location.

17. Check that all line hardware (insulators, corona rings, vibration dampers, spacers, conductor clamps, warning spheres, warning lights, armor rods, counter weights, flag socket/keys, etc.) is installed correctly and in correct locations as per

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specification and drawings. 18. Make sure that the insulators are clean and line is safe to be

energized.

19. Check that all splices are correct and installed in correct span locations.

20. Check that all jumpers are installed correctly. Ensure correct clearances between jumper and structure as well as with other phases.

21. Check that overhead shield wire/OGW(Optical Ground Wire) and associated joint box are grounded to towers as specified.

22. Ensure that sags for phase and overhead ground conductors are even and to specification.

23. Check that ground clearances meet company standards. 24. Check circuit/phase identification plates, structure numbers,

danger sign plate, etc., have been correctly installed at each structure.

25. Check line/phase correctly transposed at the specified locations (if applicable).

26. Check that washing platform and pumping system has been installed as per specification (if applicable).

27. Check solar unit for tower lighting (if applicable). 28. For terminal compound, check the following, if available, as

per contract: a. Outdoor equipment such as surge arresters,

CVTs, etc. b. Equipment structure. c. Foundation. d. Bonding of equipment / structures. e. Gravelling inside terminal compound. f. Circuit identification. g. Conductor dropper and connectors. h. Fence and gate are complete and grounded.

29. Ensure that the site has been properly cleaned up and all earthwork profiles are correct before acceptance.



1. Perform phase sequence/rotation check. 2. Perform sequence impedance and susceptance

tests and mutual impedances (both zero and positive sequence for double circuit lines.

3. Check tower foot earth resistance as per company standard.

4. Check the aircraft warning lights are properly functioning (if applicable).

5. Perform continuity and conductivity test.

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30.0 Protection and Control (Standard Reference is SEC Transmission Standard Procedures and relevant Manufacturer’s Recommendations)

30.1 Protection and Control Panels-Mechanical Checks and Visual Inspections


1. Inspect for defects and physical damage from shipping and handling.

2. Prior to opening any case or panel, confirm that the equipment will not be contaminated by dust, excessive humidity or other pollutants.

3. Ensure that there is no foreign material, moisture, dust, etc., inside panels and device cases.

4. Check all installed equipment nameplate information for compliance to approved drawings and equipment/material lists.

5. Ensure that all relays, relay covers, meters, controls and test facilities are properly identified as per the approved drawings and relevant SEC standards and that the identification does not obscure information displays.

6. Ensure the mimic bus provides an accurate representation and that all switchgear identification is accurate and as assigned by Systems Operations Department.

7. Confirm that each panel has been properly secured to the floor in its final service location.

8. Confirm that panels are constructed and wired as per SEC relevant specification.

9. For all internal and external panel wiring, confirm that all screw terminations are tight and that crimp connectors are firmly secured to the wire and to the termination point. Ensure that no part of the wire is bent at the termination point.

10. Check that panel equipment is mounted securely and protected against mal operation due to vibration, shock, etc.

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30.2 Internal Panel Wiring Tests

ITEM DESCRIPTION DONE REMARKS 1. Wiring Test / Confirmation

a. The equipment is safe to work on and free of construction activities.

b. Ensure that the approved drawings, relevant specification, protection requirement, manufacturer’s manuals, factory test results, site test procedures, etc., are available at site.

c. All necessary tools and equipment with their valid calibration certificates are available.

d. Stable auxiliary power supplies at the rated voltages are available.

e. Prior to conducting panel checks, open all supply breakers, remove all fuses and ensure that all DC (including alarm, SOE, SCADA, etc.), AC, VT and CT circuits are properly isolated.

f. Confirm all DC circuits are ungrounded. g. Check CT and VT circuits to confirm the

presence of a ground. Temporarily isolate the ground point on each circuit individually and retest to confirm that each CT and VT circuit is grounded at a single point.

h. Check the burden of each DC circuit with an ohmmeter to confirm absence of short circuits.

i. Check auxiliary power supply polarity and magnitude at the supply side of all circuit breakers/fuses to be correct as per schematics and relay/meter ratings.

j. All wiring including CT, VT, AC, control, alarm and earthing shall be confirmed terminal to terminal and wire by wire using an ohmmeter.

k. Operate all switches and relay contacts confirming connection terminal numbers and contact status using an ohmmeter.

l. Confirmed wiring is to be highlighted in yellow on the schematic diagram. Corrections/changes in the schematics shall be marked up using red pencil for additions and green for deletions.

m. For all MCBs, confirm ratings as per approved drawings; operate several times by hand. Inject 150% of rated current and record the timing for trip operation.

n. Confirm that each internal and external wire is properly ferruled at termination points.

2. CT Circuit Confirmation a. Inject AC current at about 50% of the rated

current into one phase to neutral of the

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current circuit at the incoming CT cable connection using a suitable meter and isolated current source (for each phase of each current circuit).

b. At each current test facility, confirm current flow and polarity in the subject phase and neutral as appropriate and according to the approved schematics. Confirm no current in the other two phases.

c. Withdraw each relay in the current circuit one at a time and confirm that the case shorting facility is working and that at no time during its withdraw is the current circuit opened. Check test facility shorting and isolating devices for proper operation.

d. Confirm current flow in the relay by opening the case shorting manually and confirming the meter to read zero.

e. Confirm that any phase selector switch for metering is connected in the correct phase being tested. (for each phase of each current circuit).

3. VT Circuit Confirmation a. Connect a fused or current limited adjustable

three phase, four wire voltage source to the VT circuit and slowly increase the voltage to the rated value.

b. Using a voltmeter and phase angle meter, confirm the phase angle and magnitude at each terminal in the voltage circuit according to the approved schematics.

c. Check total burden per phase to conform to expected loading as per connected relay/metering specifications.

d. Confirm that any phase selector switch for metering is connected in the correct phase being tested for each phase of each current circuit.

4. DC Circuit Confirmation a. Withdraw all removable relays and meters

from the panel. b. Apply normal DC supply (insert fuses/close

breaker) to the circuit and use a DC voltmeter to confirm all direct connections to the positive and negative supply between the fuse/breaker and the device terminals are made correctly. Confirm power supply at each relay/meter case terminals is correct.

c. Disable the DC supply and reinstall the relays and meters in the panel. Restore the DC supply.

d. Test the panel by operating (or simulating operation for external devices) each

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switch/coil/contact separately while monitoring correct circuit operation. Use a voltmeter to confirm DC voltages at progressive locations in the panel wiring. Proceed in such a way as to confirm that each contact operates only the intended devices in the panel. Confirm all contacts of control switches/relays including spares.

30.3 External Panel Wiring and Cable Tests

Cable testing requires at least two personnel with a means of communication between the cable/wiring ends. Spare cores shall be clearly identified and of sufficient length to be terminated at the farthest terminal in the panel.

CAUTION: Before conducting any external wiring or cable tests, ensure that all sources of supply to the circuits involved have been de-energized or disconnected.


1. Continuity Checks Cables and external wiring insulation shall be tested as for panel internal wiring, Section 3.30.2. All control cables shall be tested using a low ohms reading ohmmeter to check each wire separately to ground (CT and VT circuits must have their normal grounding point isolated during this test). The technician at one end shall ground one core at a time in communication with the technician at the other end who shall use an ohmmeter to monitor the cores.

2. CT Cable Checks A final check of each CT circuit shall be conducted by current injection at the source end while measuring magnitude and phase angle in the downstream circuit test facilities.

3. VT Cable Checks A final check of each VT circuit shall be conducted by voltage injection at the source end while measuring magnitude and phase angle in the downstream circuit test facilities.

30.4 Panel Device Tests

ITEM DESCRIPTION DONE REMARKS 1. Each panel device shall be mechanically inspected

prior to testing. CAUTION: When working with electronic devices, never remove modules with the DC supply energized. Use precautions to prevent static discharge damage to the modules. Grounded wrist strap, anti-static work surface and electrically conductive storage bags should be used.

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a. Check condition of internal wiring and solder joints.

b. Case cover and gasket for proper seal against dust.

c. Condition of any connectors, contacts, alignment and travel.

d. Operation of moving parts, mechanical target operation and reset.

2. Relay Tests Relay tests shall be conducted in accordance with the approved site test procedure. Additional tests may be required as recommended by the manufacturer, by Company Standard or as deemed necessary by the Company from operational experience.

a. 500 V insulation tests shall be conducted between the AC circuits and from AC circuits to the relay frame. All outputs/indications shall be tested.

b. For electromechanical relays, the DC circuits shall be insulation tested to AC circuits and to the frame of the relay.

c. Initial tests of new protective relays shall include operating characteristics checks for a representative range of available settings with Company approved computer operated test equipment running routines developed for the specific relay and test set involved.

d. Relay auxiliary devices such as external resistors, metrosils, etc., to be tested to conform to required ratings and manufacturer’s information.

e. Proper electrical operation of targets/indicators shall be confirmed.

f. Final calibration test of all protective relays must be carried out on approved settings with the relays mounted in their cases, by secondary injection at the front panel mounted test facilities.

g. Auxiliary and tripping relay testing shall include:

i. Insulation testing as above.

ii. Pickup and dropout voltage, verification of all contacts.

iii. Operation timing at 80% and 100%

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nominal voltage. iv. Time delay relays

shall be tested at 0%, set point and 100% delay.

h. Use of red and green tags for tested relays, meters, etc.

i. All the relays and meters which have been tested and found acceptable shall have green tags.

j. The relays and meters found defective during tests shall be tagged red.

3. Metering Tests Panel metering calibration shall be tested via front panel mounted test facilities. The following represent the minimum test points required.

a. Maximum demand indicator (MDI) meters shall be tested at 10% and 100% of full scale.

b. Current and voltage metering and transducers calibration shall be tested at 0, 25, 50 and 100% of scale.

c. Watt and VAR metering and transducer calibration shall be tested at (+/- when bi-directional) 0, 25, 50 and 100% of rated load and with rated voltage and current at angles of 0, 45,180, 2270 and 315 degrees.

d. KWH and KVARH metering calibration shall be tested at 10% and 100% of rated current at angles of 0, 45, 90, 180, 225, 270 and 315 degrees.

e. Frequency metering and transducers calibration shall be tested at minimum, nominal, and maximum rated scale.

f. Power Factor metering and transducer calibration shall be tested at rated voltage and at 50% lead, unity, 50% lag power factors at 10, 50 and 100% of rated current.

g. Tap position indicators shall be checked and confirmed for the entire range of transformer tap positions.

4. Annunciator Tests a. Confirm dual supply operation by

disabling primary and backup supplies one at a time.

b. Confirm operation of Acknowledge, Reset and Lamp Test push buttons.

i. Alarm indication lamp

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flashes on receipt of alarm.

ii. Pressing Acknowledge does not reset the alarm points.

iii. Alarm does not reset until Reset is pressed.

c. Confirm Annunciator Failure alarm to SCADA.

d. Check operation of each alarm point one at a time by simulating input at the marshalling panel.

e. Confirm individual alarm identification for each point during functional testing of remote panels’ output contacts.

5. Digital Disturbance (DDR) Tests a. DDR shall be inspected and

calibrated as recommended by the manufacturer.

b. Calibration of voltage and current channels shall be confirmed by secondary injection.

c. Each digital input shall be confirmed by operation of the associated auxiliary contact in the remote panel.

d. Program and electrically confirm trigger levels and initiating contacts.

e. All alarm/SOE/SCADA outputs shall be tested and confirmed.

f. Verify accuracy of all channel descriptions.

g. Verify operation to the local printer if available.

h. Verify proper communication and software

i. Update/installation at all concerned locations by establishing communications with each unit and downloading event data.

30.5 Functional Checks

ITEM DESCRIPTION DONE REMARKS 1. Test to Local Auxiliaries

With all tripping isolating switches opened, operate the protective relays by secondary injection to test all functions to the panel auxiliaries. Check and confirm correct operation of all trip, alarm, SOE and SCADA auxiliaries in the panel as well as initiation outputs to DFR, breaker failure, etc.

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2. End To End Tests Communications with the test crew at the remote end are essential to this test. Where protection signaling equipment (PSE) is used in the scheme, end to end tests shall be conducted to confirm operation of each channel individually to the correct remote tripping/protection inputs in coordination with personnel at the remote end. Round trip channel delay should be checked and recorded. Pilot Differential Protection shall be end to end tested as recommended by the manufacturer.

3. Test to Remote Functions Individually operate each control switch, protection output trip, initiation and alarm function with the associated isolating switch (if available) first in the open position and then in the closed position to prove the switch connection. Take care to limit tripping when testing to transfer tripping or breaker failure protection prior to initiating. Where no physical or visual indication of the signal is available, use a multimeter to monitor the received signal at the appropriate terminals of the remote panel or equipment. Interlocks such as close blocking from lockouts shall also be proven. Testing shall include all reclosing, initiation, trip, SCADA, SOE, annunciator and fault recorder outputs from the panel to actuate the associated remote devices.

4. Primary Injection Phase and ratio connection of CT and VT circuits shall be confirmed by primary injection and checked to the panel test facilities.

5. Stability Tests Stability of bus bar, transformer differential protection and restricted E/F protection circuits shall be confirmed by injecting current on the primary bus and simulating first internal and then external fault conditions while monitoring spill current at the protective relay.

6. Remote Tap Change Control (RTCC) a. Selection of Independent,

Master/Follower, Auto, Manual from RTCC local pushbuttons and from SCADA.

b. Raise and lower operation of the tap changer in Independent/Manual from both the RTCC control pushbuttons and from SCADA.

c. Raise and lower operation of the tap changer in Master-Follower for each possible combination of paralleled transformers, in Manual mode from both the RTCC control

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pushbuttons and from SCADA. d. Raise and lower operation of the

tap changer from the AVR relay in Independent/Auto and Master/Auto both when the RTCC is in Local and in SCADA control modes.

e. Check of blocking and reset of operating modes when breakers are opened or paralleling is disturbed.

f. Operation of all alarm, SCADA and SOE outputs from the panel and control panel.

7. Automatic control switching equipment panel a. Check the proper scheme for

automatic closing of third transformer 13.8 kV incomer circuit breaker in case of tripping of any transformer in service.

b. Check all alarms, command and back indication of the system with SCADA.

8. Trip On Parallel scheme a. Check the manual tripping of one

circuit breaker and selection of the circuit breaker to be closed and in time of tripping of that selected circuit breaker the fifth circuit breaker will closed accordingly (13.8 kV three transformers and two bus section circuit breakers).

b. Check all alarms, command and back indication of the scheme to SCADA.

9. Automatic Bus Transfer Scheme (ABTS) Panel a. Operation in service for tripping of

each transformer individually when paralleled with a second transformer to demonstrate automatic paralleling of the third transformer. If possible, offload one bus at a time so that it is possible to prove operation for loss of the independent transformer without loss of customer load.

b. Prove that protection blocking interlocks (bus differential, transformer high side time overcurrent etc.) prevent operation of the ABTS.

c. Prove scheme for opening of bus

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section breaker to break parallel of three transformers is functioning.

d. Test blocking and forced operation of the RTCC by the ABTS.

e. Operation of all alarm, SCADA and SOE outputs from the panel.

10. Automatic Transfer Schemes (ATS) a. Confirm proper operation of

station service (AC and DC) automatic transfer schemes by simulating incomer failures.

b. Confirm operation of interlocks to prevent/limit paralleling of incomer sources as per approved scheme.

c. Test automatic and manual controls for all possible operating conditions.

11. Switchgear Control Panel Functional Tests a. Checks of all interlocking and

blocking functions (synch check, lockout block closing, ground switch, etc.)

b. Tests of open and close operation and indication of the associated switchgear.

c. Operation of all alarms, SCADA and SOE outputs from the panel.

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30.6 Energization

ITEM DESCRIPTION DONE REMARKS 1. First Time Energization Testing-Checks Prior to Energization

a. All in service CT circuit shorting is removed. b. All VT circuits MCBs closed, fuses in place. c. All supplies to protection, control, switchgear,

etc., are normal. d. No abnormal relay targets, alarms, SCADA

SOE indications. e. All relays have approved settings applied and

have been fully tested and are in service. f. All switchgear and other power equipment

testing is completed. g. All protection equipment is properly labeled. h. All fire/smoke alarm systems are fully tested

and in service. i. All necessary fire fighting equipment is on site

and accessible without obstruction. j. Confirm all men and tools are clear of

equipment to be energized and that all personnel are aware of the pending energization.

2. Phasing Checks Before paralleling two sources, phasing shall be absolutely proven by selectively energizing a common three phase VT set from the two sources one at a time and checking the phasing (voltage and phase angle) of the VT set to a reference potential whose source shall remain unchanged for the duration of the test. For example, if one new incoming line to an existing station is to be energized, use the existing incoming line ‘A’ phase to neutral potential as a reference and measure and record the new line VT secondary three phase voltage and phase angles when energized from the remote end only. Then after opening the remote end of the new line, energize the new line from the local station only and repeat the voltage and phase angle measurements, the results of the two tests should be identical (within a few degrees) if phasing is correct. Where possible, phasing sticks can be used.

3. In Service Checks a. Immediately after energization, in-service/on-

load checks should be taken and recorded by measuring the magnitude and phase of all voltage and current circuits to a common reference at all of the test points available to prove VT and CT connection, ratio and polarity.

b. Check and record all panel meter readings to compare with CT/VT measurements in the control circuits.

c. As soon as sufficient load is available, all

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directional and distance type relays shall have their operating direction proven using in service voltages and currents.

d. Directional earth fault relays shall be proven by selectively isolating in service voltages and currents to provide a range of simulated fault conditions.

e. For REF and bus differential relays, check to ensure minimal spill currents in service. Test the differential circuit by isolating one service current from the summation to force operation and prove the summation circuit is not shorted.

f. For transformer differential circuits, check spill currents and minimum, center and maximum transformer taps. Spill current at minimum and maximum taps should be similar with near zero spill current on the center tap position if the auxiliary CTs are selected to the correct tap.

g. Check transformer AVR operation in independent and parallel modes as applicable. Manually raise (lower) the transformer(s) two taps and place them back in AUTO to observe the automatic return to the correct voltage tap. Confirm operation from SCADA and in all possible operating modes.

h. Functionally test the ABTS scheme by operating transformer protection to trip the breakers and initiate the system.

i. Check in service reclosing for OHTL circuits by operating the protection to initiate trip and reclose.

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31.0 Station Batteries (Standard Reference is IEC 60623, clause 4 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness as per standards. 3. Check tightness of all external wiring and cabling connections. 4. Verify all panel mounted devices (meters, switches, push

buttons, indicator lamps, etc.) are supplied and installed according to approved drawings.

5. Make sure all battery connections are clean and free from corrosion.

6. Verify system configuration and capacity with contract specification.

7. Check that all cells are properly numbered. 8. Check protective covers installed. 9. Check that all battery maintenance tools and accessories

(hydrometer, wall mounted thermometer, insulated torque wrench, rubber gloves, apron, face shield) have been provided per specifications. Ensure that all maintenance equipment is stored in a wall mounted lockable cabinet.

10. Check that the room ventilation, exhaust fan, etc., are to specification.

11. Check installation of safety equipment (eyewash, showers, ”No smoking “and “Warning Caustic/Acid” signs).

12. For flooded lead acid batteries, check for correct specific gravity and liquid level.

13. Check that all battery racks are correctly and securely grounded.

14. Check that the battery bank is provided with an isolating disconnect switch.

15. Check that the Valve Regulated Lead Acid (VRLA) battery bank has an ammeter provided for monitoring the float charge current.



1. For valve Regulated lead Acid Batteries, check the open circuit voltage of each cell.

2. Perform initial charging of the battery (equalize voltage, charging rate and charging time according to the manufacturer’s instructions).

3. Record individual cell voltage electrolyte specific gravity and cell temperatures at the end of charge cycle.

4. Battery discharge test: a. The battery must not have been discharged

within last 7 days before test is performed. b. While battery on float, read and record the

Room temperature shall be between 25

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voltage of each cell or unit and battery terminals float voltage.

c. Disconnect the battery charger and any other load on the battery.

d. Record the initial voltage of each unit and battery terminals.

e. Select the discharge rate based upon the battery capacity (ampere-hour) and the time period the test shall be carried out for 10 hours.

f. With the variable load bank (dummy load) with an ammeter in series and a voltmeter across the battery terminals, connect the load while simultaneously starting the timing device.

g. Maintain the correct current while periodically reading and recording total battery voltage. After 10 hours record the final unit voltage and compare the test result with the manufacturer’s recommended voltage chart to confirm the battery end voltage.

and 30 °C.

5. Fully recharge the battery according to the manufacturer’s instructions.

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32.0 Battery Chargers (Standard Reference is IEC 60623, clause 4 and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness as per standards. 3. Check tightness of all external wiring and cabling connections,

labeling, drawing pocket shall be checked.

4. Verify all panel mounted devices (meters, switches, push buttons, indicator lamps, fuses, etc.) are supplied and installed according to approved drawings.



1. Insulation test for all external wiring. 2. Battery charger test by simulation of variable load to check for

correct charger current output response to different values of load.

3. Check the adjustment range of output float and equalize voltage. Note that the adjustment of float and equalize voltage should be independent of each other.

4. Functional check of the following: a. High and low output voltages alarm/shutdown. b. Ground monitoring/ground detector for +ve

and –ve alarms. c. All other protective alarm/shutdown. d. All devices (switches, push buttons, timers,

indicating lamps, etc.). e. Current limits. f. Soft start. g. Impedance monitors (if applicable). h. Silicon droppers (if applicable).

5. Check output voltage ripple content (battery disconnected). 6. Check regulation at 0%, 50% and 100% of full load. 7. Measure AC input and DC output voltages and currents and

calculate efficiency at 50% and 100% of rated output current.

8. Calibrate voltmeters and ammeters. 9. If applicable measure the following and verify that they are

compatible with and meet the requirements of the communications equipment:

a. Voice band noise voltage. b. Wideband noise voltage.

10. Check load sharing operation for parallel chargers. 11. Ensure that the settings of adjusted control, shutdown, alarm

voltage, etc., have been reset to the final operational values as specified by SEC.

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33.0 AC Distribution Panels (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects including of quality of paint work.

2. Verify circuit layout for conformance with breaker directory drawing.

3. Verify correct rating of each circuit breaker per design drawings. 4. Check tightness of all bolted connections. 5. Verify that all front panel mounted devices (meters, selector

switches, push buttons, timers, indication lamps, etc.) are installed per layout drawing and are correctly labeled.

6. Check for proper grounding connection (torque wrench method).



1. Insulation test of all buses and wiring. 2.5 kV for one minute

2. Phasing check. 3. Functional check of main power contactor (or breaker). 4. Functional check of each branch breaker. 5. Calibrate voltmeters, ammeters and wattmeters. 6. Functional check of meters and phase selector switches. 7. Functional check of all auxiliary devices including individual,

group and main circuit breaker alarms.

8. Functional check of under voltage protection/alarm circuits. 9. Functional check of ground fault circuit interrupter (if applicable).

10. Check all MCBs for their ratings and alarms.

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34.0 DC Distribution Panels (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects including of quality of paint work.

2. Verify circuit layouts for conformance with breaker directory drawing.

3. Verify correct rating of each circuit breaker per design drawings. 4. Check tightness of all bolted connections. 5. Verify that all front panel mounted devices (meters, selector

switches, push buttons, timers, indication lamps, etc.) are installed per layout drawing and are correctly labeled.

6. Check for proper grounding connection (torque wrench method).



1. Insulation test for all buses and wiring. 2.5 kV for one minute

2. Polarity check. 3. Functional check of main breaker. 4. Functional check of each branch breaker. 5. Calibrate voltmeters, ammeters and wattcmeters. 6. Functional check of meters. 7. Functional check of all auxiliary devices including individual,

group and main circuit breaker alarms.

8. Functional check of under voltage protection and alarm circuits. 9. Functional check of DC transfer switches and interlocks.

10. Functional check of positive and/or negative ground alarm (calibrate resistors for proper detection sensitivity earth fault relay setting shall be checked).

11. Check all MCBs for their ratings and alarms.

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35.0 LV AC Auto-Transfer Schemes/Switches (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check that all front panel mounted devices are supplied and

arranged according to approved drawings.

3. Check that all devices and cables are properly identified and labeled.


5. Check that all grounding is correct and securely connected (including neutral bus).

6. Check mechanical/electrical interlocks.


ITEM DESCRIPTION DONE REMARKS 1. Phasing check of incomers and transfer switch connections. 2. Calibrate under voltage relays and time delays. 3. Calibrate voltmeter and ammeters. 4. Functional check of meters and selector switches. 5. Functional check of electrical and mechanical interlocks. 6. Functional check of preferred source selector switch. 7. Check transfer motor fuses. 8. Functional check of transfer operation (simulate loss of one

source) and retransfer on re-establishment of preferred source voltage. Check with each source as the preferred source.

9. Ensure the sources are from two separate buses. 10. Set under voltage relay and time delay per manufacturer’s

instructions.

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36.0 Grounding Systems (Standard Reference is IEEE 81 and relevant SEC Transmission Specifications)



1. Inspect the grounding system(s) for conformance with approved design drawings and specification.

2. Inspect the mechanical integrity and quality of all bolted and/or thermite welded grounding joints and connection.

3. Inspect and verify the size and type of conductors conform to standard requirements.

4. Check that all metal parts in the substation are grounded.


ITEM DESCRIPTION DONE REMARKS 1. Measure the ground grid system resistance by the “fall of

potential” method.

2. Measure the contact resistance at 100 A DC of all bolted and/or thermite-welded joints at the grounding conductor between the equipment to be grounded and the grounding mesh. Note that bolted below grade connections are not permitted.

3. Measure the electrical resistance between each major electrical equipment grounding point, grounded neutral points and the substation main grounding system by the “millivolt drop” method.

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37.0 Switchgear Air Compressor Systems (Standard Reference is relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check labeling and marking according to the approved

drawings.

3. Check tightness of bolts on direct drive and base-mounted equipment.

4. Check oil level and leakage and air compressor main components, air receiver tank design and specification.

5. Check hour meter, safety relief valve, pressure switch and gauges.

6. Check air lines piping according to the approved materials. 7. Check that the exposed airlines protected against rupture

damage.

8. Check that all piping runs parallel to flooring or walls and is clamped properly by u-bolts or metal clamps supported on at least 6 foot intervals or less.

9. Check that all piping has sufficient spacing so that each line can be accessed without disturbing the rest of the piping.

10. Check that all pipes are supported on steel benches on the floor of the trench.

11. Check that all piping fitting connections to be used shall be flare cup type nuts with sleeve.

12.

d. Oil level sight glass.

Check that air compressors are fitted with: a. Automatic drain valve. b. Manual drain valve. c. Pressure relief valve.

13. Check that the receiver tank provided with inlet and outlet stop valves, manual drain valve, pressure relief valve and pressure gauge.



1. Check that the motor for air compressor designed for operation on 220 V, 3 phase 60 Hz including magnetic contactors, relays and accessories.

2. Check that circuit breaker, isolating switch wires and conduit sizes are suitable for load requirement of the system.

3. Check that all wiring shall be in rigid steel conduit, wire ducts or flexible conduit; wires shall be standard type THW and color coded.

4. Check that all wiring splices shall be made with wire connector or terminal bed connectors of approved type and insulated with two layers of rubber, covered with friction tape to protect the rubber.

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5. Check that main control panel is equipped with indication lamps, change over switch, hour meter.

6. Check interlock against overload operation, single phasing of power supply, continuous operation not attended for 1-hour.

7. Check low pressure alarm, high pressure alarm, compressor faulty alarm.

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38.0 HVAC Systems (Standard Reference is manufacturer’s recommendations and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check labeling and marking is according to the drawings. 3. Check tightness of bolts on direct drive and base-mounted

equipment.

4. Check for adequate access to the equipment. 5. Check that ducts exposed to weather are properly insulated and

wrapped with weather proofing materials, e.g., wrapped with aluminum sheet.

6. Check that the space clearance around the duct shall be properly sealed to prevent the passage of rain water or any other foreign matter.

7. Check that all panels such as control panel, compressor panel, motor blower panels shall be provided with left and right handles.

8. Check that air conditioning essential components, electrical controls, breaker, etc., is properly labeled or marked.

9. Check that all exposed refrigerant suction lines are properly insulated and wrapped with aluminum sheet and suitably protected from rupture damage.

10. Check that the exposed refrigerant liquid line is painted with liquid refrigerant gas color code paint and fitted with liquid sight glass, solenoid valves expansion valves and strainer if required.

11. If semi-hermetic reciprocating compressor with nominal cap of 20 tons and above is used, check that the size of receiver tank is able to contain all refrigerant charged into the system plus 20% excess volume for gas expansion.

12. Check that receiver is provided with inlet and outlet shut off valves, relief valves, purge cock, liquid level sight glass and oil drain.

13. Check that the refrigerant compressor is a sealed hermetic type or semi-hermetic reciprocating type.

14. Check that the compressor is provided with the following: For sealed type hermetic compressors:

a. Suction and discharge service valves with charge plug fitting connection.

b. Oil level sight glass.

b. Crank case heater. c. High and low pressure cut-out manual reset.

For semi-hermetic reciprocating compressors: a. Suction and discharge service valves with

charge plug fitting connection.

c. Suction, discharge and oil pressure gauges. d. Crank case heater. e. Oil pressure protective switch to stop

compressor operation in case of lubrication failure.

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f. High and low pressure cut-out manual reset. g. Suction line strainer with service valves.

15. Check that thermostat control with temperature indicator is provided and suitable to operate the system automatically.

16. Check that the thermostat is equipped with independent switch to operate the air supply fan continuously if required.

17. Check that the thermostat control is protected by a clear plastic transparent guard cover with standard lock and key.

18. Check that the belt driven blower and fan motors are protected by a belt guard cover.

19. Check that the air filters are easily removable from unit and washable type and check that the frame is 18 gauge galvanized iron with welded or screw type corners.


REMARKS ITEM DESCRIPTION DONE

1. Check rating of all motors, magnetic contactors, relays and accessories is 220 V, 3-phase, 60 Hz.

2. Check all wiring is in rigid steel conduit, is standard type THW and color coded.

3. Check that the size of all wires and circuit breakers are suitable for requirement of the system.

4. Check that all wires splices are made with wire connectors of approval type or soldered and insulated with two layers of rubber and friction tape.

5. Check interlock to stop the compressor when: a. Condenser blower motor fails. b. Air handling unit (AHU) blower motor fails. c. Suction and discharge operating pressure

exceeds predetermined level. d. Overload operation of compressor. e. Low and high voltage in the power supply. f. Single phase of power supply. g. Compressor lubrication fails. h. When desired room temperature required is

attained.

6. Contractor shall perform the following tests prior to start commissioning of the system:

e. Operation test.

a. Preliminary test. b. Pressure test. c. Leak test. d. Control test.

7. Measure compressor continuous line current and power supply voltage. Note compressor’s discharge and suction pressure (PSIG).

8. Check indoor fan and heater current. 9. Functional check of the system.

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39.0 Dry Type Transformers (Standard Reference is relevant SEC Transmission Specifications)


DONE

ITEM DESCRIPTION REMARKS 1. Inspect for physical damage/defects (cracks, chips, etc., of the

cast resin).

2. Check nameplate for correctness. 3. Check tightness of all bolted connections (torque wrench

method.

4. Check that all grounding is securely connected, including star point neutral.

5. Perform all specific checks per manufacturer instructions. 6. Check proper operation of all auxiliary devices (as applicable).


REMARKS

ITEM DESCRIPTION DONE

1. Insulation resistance and Polarization Index (PI) test. 2. Turns ratio all (taps) test. 3. Polarity and vector relationship test. 4. Winding resistance measurement (all taps). 5. Excitation current test (at nominal tap). 6. Back energization test (at rated voltage for 15 minutes). 7. Check the off load tap changer is set at the rated voltage tap. 8. Functional test of all auxiliary devices (if applicable). 9. Control and protective circuit functional tests.

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40.0 Fire Detection and Protection Systems

Loss Prevention Department is responsible for fire detection and suppression systems, but transmission witnessing personnel shall check the alarms and trip signals (if applicable) which affect the main equipment such as power transformer, GIS, etc.

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41.0 Civil Work

Witnessing of civil work is the responsibility of the Civil Department to witness the work of the civil contractor. Transmission witnessing personnel shall check the accesses and ventilation that affects the main equipment.

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42.0 Static VAR Compensation System (Standard Reference is relevant SEC Transmission Specifications)

42.1 Pre-Commissioning Tests and Safety Measures


1. Get the sanction for test document. 2. Check the safety documents for entering the capacitor bank

area.

3. Check the safety documents for entering the TCR area. 4. Check the safety document for touching the capacitor banks

and TCRs.

5. Check the anti-static instruction prior to handling the electronic devices.

6. Never touch the components of electronic cards without anti-static wrist strap.

7. Check your safety shoes, helmet, goggles and industrial uniform.

42.2 SVC Transformer Tests

See Oil Filled Power Transformers, Section 3.1.

42.3 Harmonic Filters: Capacitors and Associated Inductors

DONE

(Standard Reference is IEEE 1303-1994, IEEE Guide for Static VAR Compensator Field Tests and relevant SEC Transmission Specifications)

42.3.1 Mechanical Checks and Visual Inspection

ITEM DESCRIPTION REMARKS 1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check leakage. 4. Check deformation. 5. Check tightness of the bolts according to specifications. 6. Check that all grounding cables are securely connected. 7. Check for any damaged paint. 8. Check earthing switch. 9. Capacitor bushing tightness check.

10. Check for bushing cracks. 11. Check for proper termination. 12. Check CT locations physically.

DESCRIPTION DONE

42.3.2 Electrical Tests

ITEM REMARKS 1. Check of test and measuring instruments calibration certificates. 2. Check of condition of battery cells of the T&M instruments. 3. Check individual insulation resistances. 4. Measure each individual capacitance.

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5. Capacitance bank insulation test. 6. Capacitance bank measurement test. 7. Capacitance and Dissipation factor measurement test. 8. Insulation power factor (Doble) test –115 kV and above. 9. Perform all specific tests per manufacturer’s instructions.

10. Megger test phase to phase. 11. Capacitance bank neutral unbalance measurement. 12. Test the inductance of the harmonic filter inductors.

42.4 Thyristor Controlled Reactor (Standard Reference is IEEE 1303-1994, IEEE Guide for Static VAR Compensator Field Tests and relevant SEC Transmission Specifications)


REMARKS


1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check for overall body deformation. 4. Check tightness of the bolts according to specifications. 5. Check that all grounding cables are securely connected. 6. Check for any damaged paint. 7. Check of foreign particles between the layers of the reactor

coils.

8. Check of any insulation cracks. 9. Check for proper termination.

10. Check CT locations physically.


ITEM DESCRIPTION DONE REMARKS 1. Check of condition of battery cells of the T&M instruments 2. Check main current path connection contact resistance. 3. Temperature measurement at different joints after energization. 4. Check the insulation resistance. 5. Inductance measurement between different cores.

42.5 Cooling System Component Tests (Standard Reference is IEEE 1303-1994, IEEE Guide for Static VAR Compensator Field Tests and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects for entire system. 2. Check nameplate information for correctness and installation of

the cooling network according to the drawings.

3. Check for the redundancy of the fluid circulating pumps in the cooling system.

4. Check pressure holding test on the expansion vessel/reservoir. 5. Check the pressure release valve and its operation on the

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expansion vessel/reservoir. 6. Check the availability of nitrogen regulating system on the

expansion tank and ensure no leakage.

7. Check the Motor and pump for leveling and alignment. 8. Check tightness of all joints and couplings of the coolant circuit

(torque wrench method).

9. Check all pipe network and cooling system to stand test pressure and operating pressure.

10. Check the unobstructed coolant circuits in all parallel paths. 11. Check the provision of control valve for inlet and outlet for all

parallel paths.

12. Check the provision of control valve for all equipment in the cooling system for replacing or repairing without any interruption to the cooling system.

13. Check the availability of pressure regulating valves at the outlet of the pumps.

14. Check the availability of shut off valve at the inlet and outlet of the pumps.

15. Check provision of replacing the pump while system is on line. 16. Check the provision of air bleeding valve at the top of all parallel

paths and at the ion exchanger/ deionizer.

17. Check the provision of leak-water collection (drainage) on the floors.

18. Check the provision to replace the resin while system is on line. 19. Check the provision to replace filters/strainer while system is on

line.

20. Check the availability of the filters at the inlet and out let of the deionizer.

21. Check the availability of the strainers at the outlet of the deionizer and at the inlet of the valves with bypass circuit.

22. Check the availability of the control valves at the inlet and outlet of each heat exchanger.

23. Ensure the outdoor piping network is stainless steel. 24. Ensure unobstructed ventilation for all heat exchangers. 25. Ensure the availability of vibration shocks for the all heat

exchangers.

26. Check, calibrate and functional test of the all temperature gauges.

27. Check and calibrate all pressure gauges, flow switches, differential pressure gauges and liquid level switches.

28. All the cooling system should be flushed over several hours, including all branches, heat exchangers, deionizers, etc.

29. Verify no leakage in the cooling system. 30. Test the coolant for purity, proper percentage of anti freezing

and anti algae before filling the cooling system.

31. Check the rotation of pumps and cooling fans. 32. Run the pumps on and off repeatedly, until no more particles

accumulate in the filters.

33. Vibration check of cooling network. 34. Sound level check. 35. Check the auto operation of ion exchanger/bypass valves with

the conductivity meter (if applicable).

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REMARKS



1. Check of condition of battery of the T&M instruments. 2. Visual check of electrical panel. 3. Insulation resistance test of motors. 4. Winding resistance measurement of motors. 5. Check the proper rating of the motor protection breakers and

perform the functional trip test by current injection, under voltage, and phase reversal.

6. Verification of current, overload, thermal, under voltage, and phase reversal settings of motor protection.

7. Check the operation of the pumps from local pump station PLC, and SCADA. Ensure the alarm signal when pump is on local mode.

8. Record the power supply input voltage and phase rotation. 9. Record starting and running motor current.

10. Check the redundancy of auxiliary power supply and operate the pumps one by one by both power sources.

11. Check the alarm and status by simulating the breaker open/ loss of auxiliary power sources.

12. Verify overload trip time of all motors by artificial single phasing of all three-phase motors.

13. Simulate the operation of pumps by loss of power, pump failure, differential pressure and running hours completion cycle and ensure automatic changeover.

14. Ensure automatic changeover time is coordinated with loss of cooling alarm time.

15. Verify start-up of standby pump on loss of supply to running pump and record the time.

16. Check PLC of cooling system for measurement of pressure, temperatures, Levels, resistively and status of pumps, heat exchanger fans and valves.

17. Check to see that monitoring signals show correct values or correctly indicate alarms.

18. Check the alarm/trip signal on loss of input voltage, pump failure, low coolant level, high and low resistivity, pressure, fellow, and temperature from all gauges, sensors and meters.

19. Check the cooling fans auto-changeover and auto operation by temperature.

20. Check the cooling fans operation from Manual and Auto from PLC control panel.

21. Check the cooling fan’s minimum run time, and on-off hysteresis.

22. Check the simulated operation of all electrical operated valves. 23. Ensure the full cooling capacity is available with one cooler

failed or out of service.

24. Display messages check for alarms and trips. 25. PLC internal battery check if present and note the date of

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replacement. 26. Check Automatic operation of de-ionizer by resistivity. Check

the conductivity measurement of the coolant to see that it drops below alarm level when new water is circulated, if applicable.

27. Check the deionizer time for recovering the resistivity, if applicable.

28. Check the minimum activation time of deionizer, if applicable. 29. Ensure that liquid coolant is electrically grounded.

42.6 SVC System Controller Computer (Standard Reference is IEEE 1303-1994, IEEE Guide for Static VAR Compensator Field Tests and relevant SEC Transmission Specifications)



1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check tightness of all bolted connections. 4. Check that the connection does not transfer stress to the

connection terminal.

5. Check operation of the cooling fan. 6. Check that the filters for the cooling fan are not dirty.. 7. All input and output cables are secure. 8. Fiber optics cables are secure without squeezing and without

severe bends.

9. All modules are properly labeled. 10. Check the panels are well ventilated with dust filter. 11. Check that the connection ports which are under use have dust

covers and all other unused ports should be sealed off.

12. Check that the connections ports are clearly and correctly identified.

13. Check that the ferrules are properly marked. 14. Card locations are clearly numbered. 15. Sequence event recorder panel check. 16. Annunciator panel check. 17. Check the labeling on thyristor towers. 18. Check of proper extractor tool. 19. Panel lighting is operating properly. 20. Check that the panel heaters are not installed. 21. Check that the terminals are furnished with isolator links. 22. Check that the wire terminals have banana sockets for the

testing purposes.

23. Check that all grounding cables are securely connected. 24. Verification against drawings and contract specification.

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ITEM DESCRIPTION DONE REMARKS 1. Check of Test and Measuring instruments calibration

certificates.

2. Check of condition of battery cells of the T&M instruments. 3. Check of hardware. 4. Check of software. 5. Hardware jumpers check. 6. Micro console and PC with software check. 7. Check of user program loading. 8. Input and output operation check. 9. Test of light guides passing from controller to TCR towers.

10. Firing pulses tests to thyristors simulation. 11. Snubber circuit testing. 12. DC functional tests. 13. Complete wiring checking. 14. Cooling system alarm checks from controller. 15. All alarms and trips initiation checks. 16. Trouble shooting guide verification with initiation of alarms. 17. Check of disconnects and low voltage switchgear by control

panel operation.

18. Check of print-out on the printer and alarm on the annunciator. 19. Check of alarms and trips to controller, annunciator and to even

recorder. 20. Check of cooling system ready. 21. Check of temperature normal. 22. Check of SVC ready. 23. Check of alarms at controller due to alarms of the transformer. 24. Check of all controller cards. 25. Low voltage tests for SVC with different firing angles, i.e., B=0

to B=90 (LIMAX=0 TO –1.0.

26. Stability test of differential protection thyristor bypass switch closed.

27. Emergency trip operation check. 28. SCADA point list testing. 29. Check of thyristor monitoring software operation. 30. Check of CB fail to close and fail to open alarm. 31. Controller over current protection level-1 tests, if applicable. 32. Controller over current protection level-2 tests, if applicable. 33. Secondary under voltage level –70% protection for immediate

trip, if applicable.

34. Primary under voltage –30% protection for 100 msec and no trip, if more the system to trip, if applicable.

35. Primary under voltage 0.6 p.u. for more than 1 sec. CB trips. 36. Secondary under voltage 0.6 p.u., TCR blocks if more than 1

sec. then CB trips.

37. UPS operation time to be checked if ac is off to the UPS. 38. UPS alarm and trip level tests.

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39. Controller cards battery replacement date check. 40. Check of Remote communication with modem to SER. 41. Final trip tests. 42. Annunciator AC and DC supply MCB operation check. 43. Watch dog of SER check. 44. Operational check of thyristor bypass switch.

42.7 Protective Relay Tests and Check of Protection Schemes (Standard Reference is manufacturer’s relay documents)

DESCRIPTION


ITEM DONE REMARKS

1. Inspect for physical damage or defects. 2. Check nameplate information for correctness. 3. Check tightness of all bolted connections. 4. Check that the connection does not transfer stress to the

connection terminal


ITEM DESCRIPTION DONE REMARKS 1. Check of Test and Measuring instruments calibration

certificates.

2. Check of condition of battery cells of the T&M instruments. 3. Test the protection relays related to transformer. 4. Test the protection relays related to HV CB. 5. Test the protections related to TCR and Harmonic Filters. 6. Check and test the modified schemes. 7. Check of alarms from the SVC local panel, and remote alarm in

the control panel and corresponding alarm to the Control Center.

42.8 SVC Energization: Sequence of Events and On-Load Tests

42.8.1 Electrical Tests (Standard References are manufacturer’s instruction manual and SEC relevant Transmission Standard))


1. SVC pre-energization check list. 2. Check the SVC energization list. 3. Confirm the final settings. 4. Operation division shall issue caution for energization process. 5. Check and follow the switching program. 6. Check that the operating division has issued a warning to the

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contractor for the Energization, copy to the Control Center. 7. Final NPS settings shall be issued to the Control Center,

Protection and Test and to 132/380 kV Projects Division.

8. Re-check and confirm final settings, except the settings of TCR temperature, pressure, flow and VarMach.

9. Check, clean and lock transformer area. 10. Check, clean and lock disconnect room. 11. Check, clean and lock filter area. 12. Check, clean and lock TCR area. 13. Remove the firing optical fibers connected to the thyristor

valves, so that the thyristor valves are tested without conduction. Red fibers only (16x3=48).

This is to avoid damage to the thyristors in case of mis synchronism between the firing pulses and voltage across the thyristor

14. Check HV CB grounding switch opened from GIS. 15. Check bus isolator closed from control room. 16. Send close command to HV CB. 17. Check the indication on SER for CB closed. 18. Verify the synchronism by indication pulses generated from the

TCU (thyristor control unit).

19. Open the CB and close with H5h harmonic filter. 20. Check the bus voltage before and after the CB close and

calculate short circuit power of the network.

21. Record measurements on the mimic panel, and MVAR meter should read –20 MVAR to confirm that the filter H5 is rated for -20 MVAR (-ve for capacitance).

22. Close the CB with filter H7 and take the similar measured above, but this time the load is –10 MVAR.

23. Open the CB. 24. Return the firing optical connections back to thyristors. 25. Open CB and close with TCR and Vref to =401 KV so that no

current flows in TCR.

26. Check the cooling starting on close command of CB from SVC room or control room or from the Control Center.

27. Check the alarm with thyristor address on removing of indication pulses fibers in PC and alarm on annunciator.

28. Check that on removing more than two fibers the SVC trips. 29. After CB open and all disconnect switches are closed. 30. Give close command to CB for TCR, H5, and H7 in service with

manual mode.

31. Make all the measurements with different loads, such as HV, MVAR, LV, SVC I, synch pulses graphs.

32. On cooling system PLC panel check all the pressures and temperatures, running of pumps and running of cooling fans, etc.

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33. Keep running for one day in auto mode. 34. Vary the voltage reference from mimic panel and check the

MVAR and alarm svc reached max capacity.

35. Check and record all the currents in protection relay panels. 36. Check current limitation/protection in SVC controller. 37. Check of regulation with full load to no load and with different

slopes.

38. Check of step response with Vref settings for 1% voltage difference and gain of 0.2,1,1.5, 3, etc.

39. Check auto recloser operation. 40. Check joint SVC operation with different bus bar configuration. 41. Check thyristor by-pass configuration mode. 42. Check of strip-chart recorder operation. 43. Check Event recorder alarms having responsibilities added. 44. Check the start inter-lock sequence. 45. Check stop sequence. 46. Record temperature measurements of TCRs at different joints

with temperature sensor stickers.

47. Auto/manual change over test. 48. Harmonic content tests. 49. Pump change over test by simulating fault in one pump. 50. Check cooling fans change over. 51. Check LV incomers change over

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42.9 Air-Conditioning Systems

The reliability of air-conditioning is very important for the SVC controller, so this part of the equipment should be tested thoroughly. For details of its pre-commissioning please refer to Section 3.38, HVAC Systems.

42.10 Fire Detection and Suppression Systems The reliability of fire detection and suppression systems is very important for the SVC System, like any other substation component. This equipment should be thoroughly tested. For details of its pre-commissioning please refer to Section 3.40, Fire Detection and Suppression Systems

precommissioning procedures of testing & commissioning

Documents

kv xlpe cables

kv lpof cables

check list index number

check tightness

sec commissioning standard

control cables

lv cables

r0 page number