sec standard

July 09, 2011

July

09,

201

1

241

TRANSMISSION CONSTRUCTION STANDARD TCS-P-105, Rev. 01

1.0 INTRODUCTION

Proper pre-commissioning of new electrical equipment is important to prove that new equipment has been properly shipped and correctly erected and installed. This Procedure highlights the necessary steps related to proper pre-commissioning of new electrical equipment.

As a general practice, all equipments must be tested in the factory before delivery to the site. Pre-commissioning testing at site is done to prove that:

No equipment was subjected to any damage during transportation. All equipments have been installed correctly. All equipment is working in coordination with other equipment, as specified. All the protection and control schemes are working in accordance with relevant

specifications and protection requirements. All equipments have been adjusted properly in accordance with approved settings. The installation is safe for putting into service.

1.1 Purpose

The main purpose of this procedure is

1.1.1 To provide guidelines to the witnessing engineer or technician to organize

work at site during the pre-commissioning test period. 1.1.2 To provide the minimum tests to be performed on the equipment by the

contractor. 1.2 Procedure

This Procedure is divided into two parts: the first part describes organizing the work at site before, during and after pre-commissioning tests.

The second part concerns the mechanical checks, inspections and electrical tests to be performed on the equipment before commissioning the equipment into service.

PART I: ORGANIZATION OF THE WORK SITE FOR PRE-COMMISSIONING PART II: MECHANICAL TESTS, VISUAL INSPECTIONS AND ELECTRICAL TESTS

PAGE NO. 2 OF 241 TCSP105R01/TMA Date of Approval: July 09, 2011


INDEX PART I: ORGANIZATION OF THE WORK SITE FOR PRE-COMMISSIONING 6

1.0 INTRODUCTION 6 2.0 PROCEDURES 6 3.0 WITNESSING COMMENCEMENT 8 4.0 ISSUING SITE INSTRUCTIONS/RECORDS 11 5.0 SAFETY & COORDINATION MEETING 16 6.0 TECHNICAL PROBLEM REPORT 17 7.0 TIME AND QUALITY MANAGEMENT 18 8.0 UNCONTROLLABLE PROJECT DELAY FORM 19 9.0 READINESS OF ENERGIZATION REPORT 20 10.0 FINAL PRE COMMISSIONING REPORT AND CONTRACTOR’S

EVALUATION20

11.0 FAULT REPORT 21 12.0 IMPLEMENTATION & IMPROVEMENT 21

13.0 ATTACHMENTS 22 PART II: MECHANICAL TESTS, VISUAL INSPECTIONS AND ELECTRICAL TESTS

47

1.0 INTRODUCTION 47 2.0 PURPOSE 47 3.0 PROCEDURE FOR TESTING OF MAIN EQUIPMENT 47

3.1 Oil Filled Power Transformer 49 3.2 Shunt Reactors 53 3.3 Bushings Inspection and Testing 56 3.4 Surge Arrestors 57 3.5 Station Service Transformers (less than 2 MVA) 58 3.6 Neutral Earthing Resistors. 60 3.7 Current Transformers 61 3.8 Potential Transformers 63 3.9 Capacitive Voltage Transformers 65 3.10 Coupling Capacitor Voltage Transformer 66 3.11 Hybrid/Gas Insulated Switchgear (GIS) 67 3.12 Metal Clad Switchgear 74 3.13 Metal Enclosed Bus Duct 78 3.14 Indoor and Outdoor Bus Structures 79 3.15 Indoor Circuit Breakers 80 3.16 Outdoor Circuit Breakers 83 3.17 Disconnect & Grounding Switches 86 3.18 Circuit Switchers 88 3.19 LV AC/DC LV AC/DC Board and Circuit Breakers (380/220/127V) 89 3.20 230kV and 380kV XLPE Cables 90 3.21 230 kV and 380kV LPOF Cables 92 3.22 110kV and 115kV and 132kV XLPE cables 94 3.23 110kV and 115kV and 132kV LPOF Cables 96 3.24 69 kV XLPE power Cables 98 3.25 13.8 kV and 33 kV XLPE Power Cables 100 3.26 LV Cables 101 3.27 Control Cable 102 3.28 Pilot Cables 103

TCSP105R01/TMA Date of Approval: July 09, 2011

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3.29 Overhead Lines 105 3.30 Protection and Control Panels. 108 3.31 Station Batteries 118 3.32 Battery Charger 120 3.33 AC Distribution Panels 121 3.34 DC Distribution Panels 122 3.35 LV AC Auto-Transfer Schemes/Switches 123 3.36 Grounding System 124 3.37 Switchgear Air Compressor Systems 125 3.38 HVAC Systems 126 3.39 Dry Type Transformer 128 3.40 Ring Main Unit (RMU) 129

3.41 Capcitor Bank Test 130 3.42 Capcitor And Associted Reactor (reactor test) 131 3.43 Fire Detection and Protection Systems 132 3.44 Civil Work 133 3.45 Static VAR Compensation System 134

4.0 PROCEDURE FOR TESTING PROTECTION RELAYS 150 4.1 General Mechanical Checks & Visual Inspection 151 4.2 General Electrical Tests 152 4.3 Guidelines for Testing Digital& numerical Protection & control Relays and IED’s 153 4.4 Auxiliary Relays 155 4.5 Timers (62) 157 4.6 Over/Under-Voltage Supervision Relays (59/27) 158

4.7 Compensation Voltage Protection -59ND 159 4.8 Trip Circuit Supervision 160 4.9 Definite Time Over-Current & earth fault protection relay 163 4.10 Inverse Definite Minimum Time (IDMT) Over-Current & earth fault protection

relay 164

4.11 Circuit Breaker Fail (CBF) Protection (50/62) 165 4.12 Bus Bar Differential Protection RELAY (87B) 166 4.13 Metrosil and Non Linear Resistor 171 4.14 Synchronism Check (25) 172 4.15 Distance / Impedance Protection relay (21) 173 4.16 Directional Over-Current and Directional Earth Fault Protection relay (67/67N) 175 4.17 Directional Negative Phase Sequence over current- 67Q 176 4.18 Line & Cable Differential Protection (87L/87C) 177 4.19 Auto Re-closer function 179 4.20 Transformer Differential Protection relay (87T) 180 4.21 Restricted Earth Fault (REF) Transformer Protection (64NP / 64NS) 181 4.22 Over/Under-Frequency & Frequency Rate of Change Protection (81/81R) 182 4.23 Automatic Voltage Regulation & Control (90) 183 4.24 Disturbance & Fault Recorders (DFR) 184 4.25 Sequence of Events Recorder (SOE) 186 4.26 Annunciator (alarm module) 187 4.27 Transducers 188 4.28 ACSE / ABTS / TOP 190 4.29 ACCS – Automatic Capacitor Control System 191


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INDEX 5.0 PROCEDURE FOR SCHEME AND FUNCTIONAL CHECKS 193

5.1 General Panel Function Tests 194 5.2 Local Control Cubicle (LCC) Panel Function Test 196 5.3 Relay & Control Panel Function Test 198 5.4 Transformer Function Test 203 5.5 Automatic Voltage Control Panel Function Test 205 5.6 Load Shedding & Under Frequency Panel Function Test 206 5.7 Bus Bar Protection Panel Function Test 207 5.8 ACSE / ABTS / TOP Function Test 208 5.9 ACCS – Automatic Capacitor Control System 209 5.10 Common Alarms Panel Function Test and Alarm Scheme Test 211 5.11 Final Trip Test 212 5.12 Synchronizing Relay 213 5.13 Bus Bar Protection Stability & Sensitivity Test 215 5.14 Stuck Breaker Protection Stability & Sensitivity Test 217 5.15 Transformer Differential Protection Stability & Sensitivity Test 220 5.16 Restricted Earth Fault Protection Stability & Sensitivity Test 222 5.17 End To End Test for Over Head Line Feeders 224 5.18 End To End Test for Under Ground Cable Feeders 229 5.19 SCADA Point List checking 230 5.19.1 SCADA Commands Tests 230 5.19.2 SCADA Back Indication Tests 230 5.19.3 SCADA Alarms Tests 230 5.20 Metering and Readings through SCADA to ECC 231 5.21 Pre-Energization Confirmation Checks 232 5.22 During Energization Confirmation Checks 233 5.23 On Load Tests 235 5.23.1 On Load tests for CT/VT Circuits & Transformer Inspection. 235 5.23.2 On Load Line/Cable Differential Protection Stability & Sensitivity 235 5.23.3 On Load Confirmation of Relay Directionality 236 5.23.4 Transformer Differential Protection on Load Stability Tests 237 5.23.5 Restricted Earth Fault Protection on Load Stability Tests 238 5.23.6 Bus Bar Protection on Load Stability Tests 238 5.23.7 Stuck Breaker Protection On-Load Stability & Sensitivity Tests 238 5.24 Recommended Test Equipment 239

6.0 SUBSTATION AUTOMATION SYSTEM (SAS) 240 7.0 SUBSTATION NOISE LEVELS MEASUREMENT 241


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TRANSMISSION CONSTRUCTION STANDARD TCS-P-105, Rev. 01 PART I: ORGANIZATION OF THE WORK SITE FOR PRE-COMMISSIONING

ORGANIZATION OF THE WORK SITE FOR PRE-COMMISSIONING

1.0 INTRODUCTION

Pre-commissioning tests for a new or reinforcement project are to be checked thoroughly and witnessed by SEC Commissioning engineer or technician. During the course of the commissioning it has been observed that at many stages the contractors are not ready and consequently the Commissioning personnel have to wait with the result that some tests may be missed or ignored. A procedure is required to check the complete readiness of the contractor before the pre-commissioning tests and prepare the commissioning engineer/technician for applying commissioning tests as per SEC commissioning Procedure. This document briefly outlines the necessary steps to be followed to ensure that contractors are ready to start the pre -commissioning in order to reduce or maintain the approved project milestones and control the quality of the commissioning tests.

The main purpose of this procedure is to provide necessary guidelines to ensure the readiness of the contractors to start the pre-commissioning testing of new or reinforcement projects and how to apply and perform the pre-commissioning tests ensuring that:

The project is ready for pre-commissioning tests. The contractor is fully equipped and ready from all aspects to start the pre-commissioning

test. The time for witnessing the pre-commissioning tests is at minimum duration with high

quality performance.

2.0 PROCEDURES

2.1 Project Management Responsibility

Project Management shall confirm the readiness of the contractor from all aspects. A joint inspection shall be conducted with commissioning personnel and the contractor to ensure the contractor’s readiness to start the project after written confirmation is received from Project Management.

2.1.1 Contents of Confirmation Letter

The Confirmation Letter shall, at minimum, contain:

Equipment is installed and has been inspected by the SEC Project Quality

Unit. Availability of contractor’s qualified manpower and testing engineers. Availability of tools and test equipment with one-year valid calibration

certificate. (With remaining validation period should not be less than three months).

Grounding resistance test result sheet with approval of SEC engineer witnessing.


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TRANSMISSION CONSTRUCTION STANDARD TCS-P-105, Rev. 01 PART I: ORGANIZATION OF THE WORK SITE FOR PRE-COMMISSIONING ORGANIZATION OF THE WORK SITE FOR PRE-COMMISSIONING

Insulation Resistance test and pre check of all wiring. Stable power supply and back up generator for testing and commissioning

shall be provided with constant voltage and frequency in case of no availability of SEC power supply. The site is safe for testing.

Approved relay settings and drawings available. Site office as per SEC requirements. Over-all approved schedule along with approved outages. Substation HVAC system is in service; required for protection/control

testing.

2.1.2 Joint Inspection

The contractor, Project Engineer and commissioning personnel shall visit the substation jointly two weeks prior to the start of the pre commissioning testing and the following points shall be confirmed. See attachment no.1

a. Site Office Facilities

The site office shall be complete with the following facilities: i. Commissioning Group Room with working table, chairs,

telephone, internet, PC and PC table. ii. Conference room with conference table, chairs, white

board, telephone and notice board. iii. Drawing/record room with filling cabinets and Operation

and Maintenance Manuals. iv. Fax. v. Proper W.C. facilities are provided with raw water for

washing. vi. Kitchen with refrigerator.

b. Site Technical and Equipment Requirements

The following shall be available at site prior to pre-commissioning:

i. Confirmation Letter for verification of Section 2.1.1. ii. Approved drawings, Scope of Work and one set of

approved drawings available for sole use of witnessing personnel.

iii. Catalogues, Operation and Maintenance Manuals, all relevant specifications and protection requirements.

iv. Factory Test results. v. Approved site test procedures and format. vi. Proper communication must be ready for SCADA if

applicable. vii. SCADA program is ready for implementation if

applicable. viii. Proper housekeeping and safety standards. ix. Approved deviations List. x. Base and Detailed Design Comments.


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c. Contractor personnel

During the joint site visit, the contractor shall demonstrate the availability of his qualified man-power and testing engineers as had been indicated in the confirmation letter. These engineers should demonstrate proper engineering practice throughout the project and adhere to proper safety procedures. During commissioning the CSD engineer withholds the right to dismiss contractor engineers that are unqualified or unsafe in their work for the sake of project progress or personnel safety. The contractor’s staff shall also include a Qualified Coordination Engineer with commissioning experience preferably in the SEC network. The coordinator’s responsibilities shall include but are not limited to the following:

i. Preparation of three week schedules and minimizing

conflicting activities ii. Follow up and update of the master commissioning

schedule iii. Snag follow up and clarifications (including discussions

with the project manager, the commissioning engineer, or the supplier / manufacturer)

iv. Follow up of the site instruction and status of the punch-list

v. Resolving any issues or clarifications that arise with the approved final setting.

vi. Making sure all equipment that require a final setting have timely submittals to prevent the delay of commissioning

vii. The ability to instruct his staff in proper test procedures and good experience in testing and commissioning.

viii. Supervising the drawing mark up process and making sure it is correct and completed before project handover.

ix. Following up site instructions or snags associated with design alterations requested by the commissioning engineer, and acquiring proper documentation, design approval and drawing corrections in order to continue the activity.

3.0 WITNESSING COMMENCEMENT

After confirmation of all the items of Section 2.1.2, witnessing can begin after two weeks.

3.1 Commissioning File

The Commissioning engineer/technician shall have a Commissioning File for each substation; the File shall include at minimum:

Single Line Diagram.

PART I: ORGANIZATION OF THE WORK SITE FOR PRE-COMMISSIONING


Approved relay settings. Site Instructions. Weekly and overall Commissioning Schedule. Minutes of Meeting. Technical Specifications. Copy of approved deviations list and Base Design comments. Letters of approval or comments issued by SEC in response to the contractor’s

submittals, especially those relating to protection equipment, test procedures and test formats.

Letters of response or clarification received from manufacturers or suppliers in response to snags issued during commissioning.

Organizational chart for site staff and testing engineers. 3.2 Site Instructions/Records and Project Punch List/Snags Rectifications

Commissioning personnel are responsible for witnessing the pre-commissioning tests for reinforcement and new substations. During the course of witnessing, the necessary Site Instructions (S.I.) are issued which indicate the deficiencies in fulfilling SEC relevant Standards, SOW, workmanship, safety and common operation and maintenance problems.

Sometimes differences have been noted in the S.I.s issued by different engineers on a particular point. Therefore guidelines are required for issuing S.I.s. This document briefly describes the guidelines to be followed by all Commissioning personnel to issue S.I.s in order to achieve uniformity and consistency. It should be kept in mind that this is a guideline only and it will not supersede any SEC relevant Specification in any manner.

3.3 Sequence of Events

Any items contrary to SEC Standards, SOW, workmanship and safety will be

reflected in the deficiency section of the Register File. (Attachment No. 2) The Register File has two sections; one section belongs to the activities (Attachment

No. 3) along with the single line diagram to help an engineer to visualize the project and the other section for the deficiencies.

After one week from the registration of a deficiency in the book, all outstanding items will be sent to the Project Engineer via Site Instructions/Records (Attachment No. 4)

Weekly, there is a Safety & Coordination meeting where the CSD engineer and the contractor commissioning engineer will review their safety performance and coordinate next week’s activities. (Attachment No. 5)

Bi-weekly, the status of the punch list has to be issued by the contractor on the SEC format. (Attachment No. 6)

One month prior to the scheduled energizing of the equipment, the categorized deficiency list shall be issued by the commissioning personnel to identify the items which must be corrected prior to energization. (Attachment No. 7)

The time utilization statistics sheet must be filled in daily. The number of hours lost should be filled correctly, see (Attachment No. 8).


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If the commissioning activities are halted for an uncontrollable reason, the Uncontrollable Delay Form will be used to document the start, duration, and reason for the halt in commissioning. (Attachment No. 9)

Any Item that needs to be followed up in multiple worksites will require a technical problem report. (Attachment No. 10)

The commissioning engineer / technician shall review the applied final settings during the project closing stages before energization and use this format to confirm the proper application of the approved final settings.(Attachment No. 11)

The Commissioning engineer/technician shall issue a final Pre- commissioning Report at the end of the project. (Attachment No. 12)

Once all the work is complete on the equipment, and the equipment is ready for energization, The Readiness of Energization Report shall be filled by project CSD head engineer and he is responsible for sending this report to commissioning division manager. (Attachment No. 13)

The commissioning engineer/technician shall fill Contractor’s Performance Report at the end of the project to evaluate the performance of the contractor. (Attachment No. 16)

If there is any fault occurred during commissioning in live substation or during or after energization a new substation, Fault report shall be prepared by commissioning head. The fault report is important to describe a fault and determine responsibility of the fault.(Attachment no.18)

ATTACHM

ENT NO. DESCRIPTION REMARKS

1. Joint Site Visit Checklist

The contractor, Project Engineer and commissioning personnel shall visit the substation jointly to confirm the readiness of the worksite for commissioning.

2. Register Book/Deficiency Record

The Commissioning engineer/technician shall record all the items contravening safety, SEC Standards, Scope of Work and workmanship on the Deficiency Record.

3. Register Book/Activity Record

The Commissioning engineer/technician is responsible to daily update site activities to help any engineer to familiarize him with the status of the project.

4. Site Instructions After one week from recording in the Deficiency Record, incomplete items will be conveyed to the Project Engineer via the Site Instructions Form.

5. Safety & Coordination Meeting

Purpose of this form is to set norms to assure safe work environment and a proper coordination between the entire parties.

6. Status of the Punch List Bi-weekly the status of the punch list shall be updated by the contractor.

7. Categorization of the Punch List

One month prior to energizing the equipment, the categorized deficiency list shall be issued by the commissioning personnel to identify the items to be done before energization.


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8. Pre-Commissioning

Time Utilization Statistic Sheet

The commissioning engineer/technician shall fill in this sheet on a daily basis.

9. Uncontrollable Project Delay Form

Purpose of this form is to set norms so that uncontrollable delay in project energization will be documented, monitored and coordinate with the concern department in order to avoid it

10. Technical Problem Report

Problems that arise during commissioning that are not limited to a single project require the issuance of a Technical Problem Report to prevent this problem from occurring in future installations.

11. Confirmation of applied final settings

The commissioning engineer / technician shall review the applied final settings during the project closing stages before energization and use this format to confirm the proper application of the approved final settings.

12. Final Pre-Commissioning Report

The Commissioning engineer/technician shall issue a final Pre- commissioning Report at the end of the project.

13. READINESS OF ENERGIZATION REPORT

The Readiness Of Energization Report shall be filled by project commissioning head engineer and he is responsible for sending this report to commissioning division manger.

14. Sample Check (Optional Agreement)

In order to reduce the pre-Commissioning time the “sample check” procedure may be exercised based on the contractor’s previous performance and the last time utilizations status sheet. This shall be based on agreement between the contractor and SEC Transmission.

15. Check List The check list is intended to provide information to the commissioning engineer/technician who are assigned to inspect the contractor’s work and witness commissioning testing on behalf of SEC.

16. Contractor’s Performance Report

The commissioning engineer/technician shall fill this form at the end of the project to evaluate the performance of the contractor.

17. Procedure Improvement Form

To be used to formally request an update or an improvement to the existing procedure.

18. Fault Report Fault report shall be prepared by commissioning head. The fault report is important to describe a fault and determine responsibility of the fault

4.0 ISSUING SITE INSTRUCTIONS/RECORDS

Site Instructions (SI) shall conform to the following:


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The Site Instruction will be issued on a standard format, see Attachment 4. Every site instruction will be allocated with a number prefix and a letter P (Protection),

S (Testing of Substation Equipment), L (Overhead), U (Cable), O (Operations) and FM (HVAC, Building), etc., with date.

The S.I. will be issued to the site project engineer who will hand over the same to the contractor.

Deficiencies in the drawing/literature, tools and test equipment, etc., shall be conveyed without S.I. Number with one week’s notice and if not corrected within a week the same to be issued with an S.I. Number. This also shall be discussed with the section head for further guidance.

While issuing an S.I., necessary reference to the drawing No., sheet No., specification No., P.R. and design approval stage comments, etc., must be indicated.

A copy of the S.I. signed by the Project Engineer and Contractor will be kept in the commissioning file.

Some of the instructions although necessary, cannot be implemented due to Contractual terms, lack of wording in the Scope of Work, unclear P.R., etc., are to be filed with proper remarks in the respective substation file for implementation at a later stage. Such items shall be communicated to Engineering & Design Department for inclusion in future Projects.

The contents of the S.I. can be categorized under various headings as noted below. The common Snags/Punch list mentioned will be issued once in one S.I. for the whole substation and repetition of the same for different bays shall be avoided.

4.1 Equipment not fit for Service

This consists of the following deficiencies relating to protection, metering and control equipment. Missing equipment. Physical damage to the equipment. Rating is not matching with relevant specifications. Equipment with internal fault causing incorrect test results. The equipment is not on the SEC Approved Manufacturer’s List.

4.2 Deviations from SEC Specifications

Examples are listed as follows:

Protection or a part of it is not in line with SEC relevant Specifications and/or

Protection requirements. Work has not been executed in line with general requirements or has not been

approved during the design stage. Design comments have not been implemented for the protection scheme and other

equipment.

4.3 Poor Work Quality

Examples are listed as follows:


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Segregation of protection CT and VT cables is not maintained and color coded cables are not used.

Poor ferrule printing quality which will fade over time. Cables are directly terminated on terminal blocks without providing adequate

clearances for access during troubleshooting or maintenance. Equipment or terminals are not sufficiently accessible to allow maintenance. Ferruling method does not meet relevant specifications. Apparatus is not properly labeled. Wiring has either wrong ferrules or no ferrules. Improper use of terminal lugs. Control cables do not carry proper number tags. Proper wiring dressing has not been done in panels. Labels with incorrect spelling, uneven engraved letters, improperly aligned, letters

too small, badly cut edges, etc. Alarm annunciator labels/text with letters too small to read from a distance, and

acknowledge/reset/test push buttons are difficult to reach locations. Congested wiring obstructs other terminals on a terminal block. Very loose plug/socket arrangement. These should always be locking type. Improper locking of panel doors has caused frequent breaking of the panel door

locking mechanism. Adequate illumination does not reach all working places, terminals, in the panel, in

front of relays, etc. Terminals, auxiliary relays, flag relays mounted at very low level or very high

level. Wiring not supported properly causing undue termination tension, which may result

eventually slipping of wire/breaking off from crimp. Bad crimping of wires. For CT circuit this is most dangerous as this may lead to

open circuiting of energized circuits. Open circuited energized CT circuits may cause fires and serious electrical hazards.

Inadequately rated relays used for continuously energized relays in fail safe, scheme, etc.

4.4 Improper Electrical Scheme

A protection scheme may not operate properly in spite of implementation of the relevant specification. Examples are listed as follows:

Pole discrepancy in tripping of the required CBs. Alarm is not working, either locally or remotely. Problems with auto re-closing. Problem with the inter trip scheme. Absence of anti pumping operation. This can be dangerous if the anti pumping

fails to operate. D.C. supervision scheme is not working. Trip circuit supervision scheme is not working properly. Improper operation of auto switching (ABTS) scheme. Improper operation of distance relay accelerating scheme. Problems with closing selection, interlock wiring, close lockout relay elements. Relay flags not working properly due to mechanical problem or other reasons.


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Alarm does not operate due to very fast resetting of main protection relay contacts. Auto re-closing scheme does not work correctly due to like failure of synchro-

check relay, inadequate duration of start pulse, etc.

4.5 Updating of Records

Examples are listed as follows: Equipment is missing from the apparatus list. Rating, contact arrangement and ordering number is incomplete. Cross-references are missing or incorrect. Correct catalogues have not been provided. Testing procedures are not available for some relays. Pre-check and commissioning drawings copies are required to be updated for

modifications and corrections, using red for addition and green for deletion. This has not been done correctly.

Print-out of final setting implemented for all relays should be available Proper test record forms are not available to record the test results. Some drawing sheets missing. Factory test results not available at site.

4.6 Common Punch List/Snags.

The following Punch list/ snags are found repeatedly in substation construction. Most of them are clearly mentioned in the SEC Specifications/General Requirements. Irrespective of this fact, they are usually repeatedly discovered. When these types of points are raised at site, the contractor generally tries to avoid implementation. Every effort should be made to have the contractor promptly correct the inadequacies. Some examples are listed as follows:

Color-coded cables shall be used for control and/or alarm functions and (as per existing specifications).

Quality of printing and the placement of ferrules are poor in many cases. While terminating cables, the contractor does not leave any margin inside/outside

the panel for re-terminating the cables in another location in the same panel, in case it is required.

While laying cables, segregation is not maintained section-wise, so that in case of fire in one section the other sections will also be affected.

Paralleling of alarms is done with software, whereas it is necessary to do this with help of wiring for system reliability.

Equipment lists do not correlate with the installed equipment and details such as ordering number and the numbers of NO/NC contacts, etc., are not correct.

More than one earth point has been made for the CT’s feeding the unit protection, e.g., Restricted Earth fault, Differential, Breaker Failure and Bus bar protection.

From the maintenance point of view the access to relay terminal blocks is very important; some contractors do not pay enough attention to this.

Positive (+), Negative (-) and trip marked in red are not provided on the relevant wires.

Contractors do not allocate fault recorder channels as per SEC specifications.


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Site modifications are not properly reflected in the drawings. CT shorting and isolating arrangement is not in line with SEC standard

arrangements including shorting/isolating, instruction and caution notices. Lack of proper labeling to the protection and control equipment in different

location, e.g., relay panels, control panels, LCC and AVC panels, AC/DC distribution boards, power transformer marshalling kiosks, CB isolators and earth switches, etc. This equipment includes main relays, auxiliary relays, contactors, trip relays, MCB’s terminal blocks, points on the test switch (MMLG or ABB type), trip links and other links used for other specific functions.

CT and VT protection cables are not segregated. Terminal block wiring is too low for convenient access, especially CT shorting and

isolating switches. These shall be at working height level. Crimping of terminal lugs is not done properly, particularly for CT and VT wires. Length of the metallic part of CT and VT lugs is not enough to provide proper grip

when they are tightened in the terminal blocks. Plug in type miniature relays are used in tripping and interlock circuits. After a

period of time, these relays do not function properly, due to displacement from their original position.

Normal earth switch was used on the line instead of high-speed type. In one substation, the backup main protection was found not working when the DC

supply to the first main protection was switched off since the isolator image was controlled by the first main DC supply.

Power cables for the fans from the AC distribution board to the transformer marshalling kiosk were found underrated.

Protection coordination of MCB’s installed in the DC distribution board was not maintained, so the contacts of an ON/OFF switch were burnt due to a short circuit in the DC wiring.

During on-load checks 12 volts were observed across the CT terminals of feeder cable protection.

The manual mode status of the Halon was found not annunciated. As per SEC specifications it is necessary to install an independent synchrocheck

relay for manual and auto re-closing for each CB rated 110 kV and above. The bus-bar protection trip logic for double bus-bar substations does not conform to

SEC specifications. The annunciator output contacts did not follow the initiation when the input was

reset as per SEC specifications. Remote end breakers also trip in case the HV E/F relay of transformer operates. It

should only trip the local breaker. The A/R did not close the breaker when the D.E.F. tripped the breaker. It was due

to the tripping of the breaker in advance before the initiation of the A/R.) All spare contacts for distance & Diff. relays should be wired up to terminal blocks. The phases R and B were found interchanged for the reactors. Two phases of earth switch were on one side of the CT’s whereas the third one was

on the other side of CT’s. CT polarity if it was left reversed on one of the spare feeders and the loading of the

spare feeder led to operation of BBP. The anti pumping circuit is not operational for CBs. This deficiency will lead to re-

closing of the CB on to fault when a long duration closing pulse is initiated.


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The pilot wire protection 87PW is commissioned with reverse pilot; this will lead to indiscriminate tripping.

The DEF relay for one circuit is commissioned with wrong direction this will lead to indiscriminate tripping of the circuit.

All alarms and trips for Aux. Tr. Should be added in scheme

The following items were found missing: Labeling of spare cores with cable numbers. Provision of 10 % spare terminal blocks in each relay panel, control panel, LCC,

etc. Provision of 10 % spare annunciator windows. Provision of cover on emergency trip push button. Availability of proper lighting arrangement in 13.8 kV and 33 kV switchgear

panels, relay panels, control panels, AVC panels, AC/DC panels and all marshalling kiosks.

Proper test facility for indicating and recording meters. Test facility for indicating lamps. Provision of indicating lamp extractor tool. Labeling of the duty CT cores. Labeling of CT primary polarity, e.g., P1 and P2. CT neutral looping with metallic jumpers. Labeling of relays, pressure relief devices, oil temperature gauges and winding

temperature gauges, etc. Blocking of spare plugs. Avoiding use of plug in connections and plug-in type auxiliary relays.

These problems will be updated regularly as needed

4.7 Clearing the Punch List/Snags

It is very important to clear the Punch List/Snag items as soon as possible after confirming their implementation. Sometimes it is very difficult to confirm their implementation once the substation is energized, if they are not cleared during the pre-commissioning stage. It is very useful that the witnessing engineer/technician keeps the site instruction records updated by putting his signature with date without any delay after inspecting and approving the relevant snag.

5.0 SAFETY & COORDINATION MEETING

5.1 DEFINITION

It is a site meeting between the concerned parties who will discuss a selected safety subject as well as revision of three weeks schedule and any other project related issue.

5.2 SCOPE

This Policy shall be applicable in Commissioning Services Department (CSD).


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5.3 PURPOSE

Purpose of this form is to set norms to assure safe work environment and a proper coordination between the entire parties.

5.4 POLICY

Safety and loss prevention plan must be given top priority over all other activities during project so that no loss should occur to manpower and equipment. So its constant revision and updating is necessary. Also progress of work schedule and clearance of deficiencies/punch list should be regularly monitored so that project may complete in due time.

6.0 TECHNICAL PROBLEM REPORT

Some problems that arise during testing and commissioning are not limited to a single substation.

The problem may involve:

A common manufacturer defect A common misunderstanding of SEC standards, specifications, and contractual terms on

the contractor’s behalf A common malpractice by the witness engineer / technician or misunderstanding of the

approved test procedures or misapplication of these procedures. A safety or protection problem in typical substation design or contradiction of issued

SEC standards In these situations, the procedural use of a deficiency record and possibly a site instruction will rectify the situation in that specific substation. However, to prevent this problem from occurring in future installations, the commissioning engineer / technician is required to issue a Technical Problem Report.

Technical problem reports (TPR) shall conform to the following:

The technical problem report will be issued on a standard format, see Attachment 10. The technical problem report does not eliminate the need to follow up the problem

with a snag and site instruction at the incident substation/ project. The report shall include a clear description of the problem. The report shall include a history of occurrences in other projects and associated

documentation (snags / SI). All relevant materials (manuals, manufacturer letters of clarification, formal

communication with the contractor, fault records and analysis reports …etc) to be attached with the report as supporting documents.

The report shall be sent to the technical support and coordination division to inform them of the problem.

The technical support and coordination division is responsible for archival, circulation and follow up the report with the relevant departments in SEC.


PAGE NO. 17 OF 241


7.0 TIME AND QUALITY MANAGEMENT

The following sections listed below elaborate the techniques to ensure that all equipment tests are done with optimal use of the time available.

7.1 Check List

The Check List is intended to provide information to commissioning personnel who are assigned to inspect the contractor’s work and witness commissioning testing on behalf of SEC to verify that substation and transmission line equipment and system are acceptable as per SEC- Standards and Specifications. The listing of commissioning checks and tests are based on the SEC- Commissioning Procedure.

7.2 Time Utilization Statistic Sheet

A time utilization statistics sheet is being included in this Procedure. This sheet must be filled in daily. The contents of this sheet will be used for planning future projects by using the total time consumed. Moreover this sheet will also allow corrective measures to be taken to reduce the pre-commissioning time. The number of hours lost should be filled correctly, see Attachment No. 8.

7.3 Testing Schedule

In order to start witnessing after two weeks from confirmation, the contractor shall submit to SEC the testing schedule, giving details for each test of the time and the commissioning personnel required. SEC commissioning engineer / technician shall review the schedule and give comments to the contractor on the schedule in the interest of maintaining the quality of the work or improving the performance of the commissioning period. Every week, the contractor shall submit a three-week testing program giving details of the previous week’s completed jobs and the current and following week’s proposed jobs. If in the previous week, some job was not completed, a reason for the deferral and its effect on the overall schedule should also be mentioned. SEC commissioning engineer / technician may also review this three week schedule before it is sent to the project manager and advise the contractor accordingly.

7.4 Marked Up Drawings

The contractor is responsible to provide 4 copies of each approved schematic drawing before commissioning testing starting and stamped as the following: 1. COMMISSIONING COPY (must be included by any modifications in pre-check

copy or during commissioning testing)

2. SEC COMMISSIONING OFFICE COPY

3. CONTRACTOR SITE COPY

4. PRE-CHECK COMMISSIONING COPY (HIGHLIGHTED DURING PRE-

CHECKING)


PAGE NO. 18 OF 241


The contractor is responsible to make three good colored copies from final updated marked up commissioning copy at the end of commissioning stage in order to expeditiously finalize the as-built drawings without using the substation marked-up drawing. The three copies of the marked up commissioning copy shall be distributed as the following:

SEC protection & testing division copy.

SEC commissioning Serviced Department copy, to be used for review and

verification of the As-built drawings before issuing the Final As-Built.

Contractor copy to prepare the as-built drawing.

The original final updated marked up commissioning copy will remain in the substation for maintenance purposes till the completion of final As-Built Drawings.

The contractor may want to keep one copy of substation schematics without mark-up for emergency use or replacement of lost drawings.

7.5 Sample Check (Optional)

In order to reduce the pre-Commissioning time, “sample checks” could be exercised based on the following criteria, see Attachment No. 14.

If the overall rating of the contractor performance in his immediately previous

contract was GOOD. If the hours lost due to the contractor is less than 5% of the work, for the last time

utilization statistic sheet.

8.0 UNCONTROLLABLE PROJECT DELAY FORM

8.1 DEFINITION

Any delay which is out of CSD control and leads to stop the project commissioning activities or delay in equipment energization and ultimately cause a significant delay in project commissioning planed completion date is called an uncontrollable project delay form.

8.2 SCOPE

This Policy shall be applicable in Commissioning Services Department (CSD).

8.3 PURPOSE

Purpose of this form is to set norms so that uncontrollable delay in project energization will be documented, monitored and coordinate with the concern department in order to avoid it.


PAGE NO. 19 OF 241


8.4 POLICY CSD is committed to the timely completion of commissioning of transmission projects with high quality standards. In view the above; any uncontrollable project delay as delay of energization or outage shall be documented. Uncontrollable delay event period shall be calculated and the cause of the event shall be investigated and accordingly the required action to overcome such event shall be taken.

9.0 READINESS OF ENERGIZATION REPORT

The Readiness of Energization Report shall be filled by project commissioning head engineer and he is responsible for sending this report to commissioning division manger.

The report must conform to the following mandatory requirements to give clearance for energization:

Marked up drawings have been completed Final Relays Settings have been applied and its test results have been signed. All Commissioning tests are complete and all test results are filed and available Sequence of Events (SOE) report is received Operational and maintenance manuals are received Final Trip test has been completed successfully (through the relay contact) as per the

procedure in section 5.11 All original soft ware of all digital or numerical relays & devices have been received.

The official three signatures shall be included:

Commissioning Head Engineer SEC project department engineer Contractor project manager

10.0 FINAL PRE COMMISSIONING REPORT AND CONTRACTOR’S EVALUATION

Project completion depends on the pre commissioning report, which has to be issued by the commissioning engineer/technician (Attachment No. 12). In case of separate contractors working on the same substation (lines and substation), the line-commissioning engineer/technician shall provide a copy of the final reports to the substation-commissioning engineer/technician and vice versa. Each commissioning engineer/technician shall evaluate the contractor at the end of the project, see Attachment No. 16.

10.1 Final Pre-Commissioning Report

The commissioning engineer/technician shall issue the Report based on but not limited to the following.

The status of the Punch List (A, B) for which “A” refers to any deficiency requiring

an outage to clear it or equipment damage or a safety requirements. “B” is any deficiency other than “A”.


PAGE NO. 20 OF 241


Marked up drawing are available at site in good condition. One copy of marked up drawings is complete and handed over to Maintenance

Department library for as-built drawing verifications Emergency contact list provided. Operation spare parts are available. Operation and Maintenance Manuals are available. Test results provided. All final settings applied as per the original copy of the issued final settings

documents and the commissioning engineer / technician has filled out the necessary final setting confirmation formats.

All site tests completed. Test completion and energization of station service transformer. Test completion and energization of HVAC.

10.2 Contractor Evaluation

The commissioning engineer/technician shall use SEC format to evaluate the contractor using the following criteria:

Quality of the work. Availability of qualified manpower. Availability of proper tools and test equipment. Quality of supervision/testing engineer. Safety. Cooperation. Punctuality.

11.0 FAULT REPORT

Fault report shall be prepared by commissioning head who worked at certain site which at a fault had occurred during his working period. The fault report is important to describe a fault and determine responsibility of the fault; fault report form shall be filled see attachment no.18

12.0 IMPLEMENTATION & IMPROVEMENT

The commissioning process is under continuous pressure to complete the testing and commissioning of electrical projects in the shortest duration and at the highest quality possible. The safe energization of the company’s assets is key to the success of this process and so the commissioning team is continuously finding ways to improve their work, increase the quality of their output, and reduce the time required to achieve the commissioning goals.

To achieve these goals, proper implementation of this procedure is essential. The following steps need to be given special consideration, for implementation of this procedure:

An appropriate coordination is required with Project Management. The major problems must be reported to the Commissioning Manager/Senior Engineer

for guidance.


PAGE NO. 21 OF 241


Every effort should be done to ensure that this procedure is implemented. This procedure shall be included in the Scope of Work. The contractor/Project Management Engineer shall return all the dismantled material to

SEC store. It is recommended to store a Project Commissioning File, which includes critical Punch

List/Snags, contractor evaluation, final commissioning report, single line diagram, Minutes of Meeting and Relay Setting Sheet in the substation.

Within the context of continuous process improvement, the Pre-commissioning Test Procedure itself may require a revision or an update from time to time. This will mainly be due to:

Changing trends in power protection relaying, example IED’s. The introduction of new equipment into the Transmission network such as active power

compensators and power factor correction equipment. Expansion of the network to interconnect with external networks in the GCC or the

introduction of different technologies such as HVDC transmission. The change in international standards for protection equipment and testing and

commissioning of these items.

We have supplied a Procedure Improvement Form (Attachment No. 18) in this procedure for the purpose of documenting and then implementing the improvement requests. This form is to be filled out indicating the portion of the procedure to be revised, the comments on the existing procedure, the type of improvement desired (correction, elaboration, addition). Any related documents (standards, designs, test formats, manuals) that are the basis of this request are to be attached with the form and sent to the Technical Support & Coordination Division in the Commissioning Services Department for their information and action.

13.0 ATTACHMENTS


PAGE NO. 22 OF 241



PAGE NO. 23 OF 241

ATTACHMENT NO. 1

Joint Site Visit Checklist Commissioning Services Department Contract No. Project Title / Substation Number Date of visit S.N Requirements before starting of SEC witnessing: YES NO N/A

1 Site Conditions a. Testing area is free from all construction activities. b. Adequate cleanliness and housekeeping. c. There is no safety hazard in the testing area and its vicinity. d. Stable power supply is available for testing purpose.

e. Adequate cooling/heating arrangement as the case may be, is

available in the control room.

f. Adequate lighting is provided to safely carry out the testing

activities.

g. Availability of SEC commissioning staff office(two office-

computer-printer- telephone – internet - cupboard)

h. Conference room and meeting facilities

i. Required facilities for commissioning (table -chairs-suitable and

safe furniture)

j. Completion of major civil works including grounding

k. No disturbances like sound of drilling, hammering, cable pulling

and other such activity are not allowed at the place of testing when witness testing is going on".

l. Completion testing grounding network.

m. Availability for emergency equipment's(First aids, fire fighting ,

etc)

2 MAIN EQUIPMENT AND DEVICES.

All main equipments ( power transformers - GIS - switchgear - Auxiliary transformers - batteries - air conditions - fire fighting - compressors if needed,...etc.), all panels ( control - relay - LCC - AVC - BBP- ACSE- ACDB - DCDB - COMMUNICATION PNAELS - HVAC, ... etc. ) And all protection relays, control, measuring, HMI, network switches, bay control devices, computers, GPS, Ethernet and fiber optic connections and serial connections ( for SAS ) must be installed and connected.

3 Tools and Equipments

All the tools and equipments with valid calibration certificate shall be

available at site.

4 Documents 1. Commissioning File Including:- a. Protection Requirement (PR) b. Approved Operation Single Line Diagram(SLD) with CT&VT c. Approved relays settings

d. Site instruction




PAGE NO. 24 OF 241

S.N Requirements before starting of SEC witnessing: YES NO N/A

e. Weekly and overall schedule f. Minuets of meeting g. Technical specification h. Copy of approved deviation list and base design comments i. comments from PED. j. list of qualified testing staff and who is responsible for safety. 2. Specifications 3. Approved Base Design for: GIS TRANSFORMER ELECTRICAL BASE DESIGN (33&13.8KV) SWGR BATTERY& BATTERY CHARGER Aux. Transformer SCADA & TELECOM NER RMU FMK&SMK CAPACITOR BANKS PILOT BOX 4. Factory Test Results for: GIS TRANSFORMER RELAY& CONTROL (33&13.8KV) SWGR AC&DC PANELS BATTERY& BATTERY CHARGER Aux. Transformer CAPACITOR BANK

HMI, network switches, bay control devices, computers, GPS ( for

SAS )

SCADA & TELECOM NER RMU FMK&SMK CABLES PILOT BOX

5. APPROVED SCHEMATIC DRAWINGS with the following stamps: COMMISSIONING COPY(must be included by any modifications in pre-check copy) SEC COMMISSIONING OFFICE COPY CONTRACTOR SITE COPY PRE-CHECK COMMISSIONING COPY (HIGHLIGHTED AFTER CHECKING)

6. APPROVED SITE TEST PROCEDURES & FORMATES.( for all

equipments), (TCS-P-105)




S.N Requirements before starting of SEC witnessing: YES NO N/A

7. SCADA point list should be available and submitted to ECC. 8. CATALOGUES (manuals). ( for all equipments) 9. AVAILABILITY OF REGISTER BOOK

10. AVAILABILITY OF 100% PRE-CHECK TEST RESULTS (

including the insulation test for all cables)

11. AVAILABILITY OF ORIGINAL SOFTWARE AND LINK

CABLES FOR ALL DIGITAL RELAYS AND DEVICES, COMPUTERS HMI'S AND BAY CONTROL DEVICES.

12. AVAILABILITY OF CONFIGURATION FOR ALL DIGITAL RELAYS AND DEVICES, COMPUTERS HMI'S AND BAY CONTROL DEVICES AND ALL APPROVED FROM MANUFATURERS.

13. AVAILABILITY OF ENOUGH NUMBER OF QUALIFIED

TESTING ENGINEERS TO ACHIEVE OVERALL TESTING SCHEDULE.

5 COMMENTS:

1- The snags which are quite common and permanent repetition should be considered and are been working for clearance.

6 Attachments:

Type of Attachments: ----------------

For SEC For Contractor

Names Signature Names Signature PMD CSD


PAGE NO. 25 OF 241


ATTACHMENT NO. 2 Register Book/Deficiency Record

COMMISSIONING SERVICES DEPARTMENT

Project Title: Substation Name/Number:

Sr.# Deficiency Issued by Issued Date

Status * Assigned Punch list/ Snag No.

* Date of assigning Punch list/

Snag

* S.I #

*Required to be filled if the deficiency is not cleared in week time. To be filled by commissioning engineer/technician.

TCSP105R01/TMA Date of Approval: July 09, 2011 PAGE NO. 26 OF 241


ATTACHMENT NO. 3

Register Book/Activity Record

COMMISSIONING SERVICES DEPARTMENT Project Title: Substation Name/Number:

Sr.# Date Brief of the Activities Contractor Engineer

Name

Witnessed by

Remarks

To be filled by commissioning engineer/technician.




ATTACHMENT NO. 4

Site Instructions

Site Instructions / Records No. ______

Substation Circuit Contract No رقم المشروع Project Title اسم المشروع Contractor Name اسم المقاول Attention Mr. لعنلية السيد

Contractor SEC Issued by Prepared by Name Sign Job Title

TCSP105R01/TMA Date of Approval: July 09, 2011 PAGE N. 28 OF 241


ATTACHMENT NO. 5

SAFETY & COORDINATION MEETING

Extra Pages: Date Issued by CSD:

Contract No.: PROJECT TITLE:

WEEK NUMBER :

MEETING DATE :

FORM: WEEKLY SAFETY & COORDINATION MEETING BI-WEEKLY SAFETY & COORDINATION MEETING

FIL

LE

D O

N W

EE

KL

Y

& B

I-W

EE

KL

Y B

AS

IS

SA

FE

TY

SAFETY SUBJECT:

WEEKLY COORDINATION MEETING:

1. Revision of three Weeks schedule YES NO 2. Revision of Site instructions YES NO

FIL

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D O

N

BI-

WE

EK

LY

B

AS

IS O

NL

Y BI-WEEKLY COORDINATION MEETING:

1. Updating of Punch list item YES NO

Commissioning Engineer Name Commissioning Engineer Signature

TCSP105R01/TMA Date of Approval: July 09, 2011 PAGE N. 29 OF 241


ATTACHMENT NO. 6

STATUS OF PUNCHLIST CONTRACT #: PROJECT TITLE: S/S NAME/NUMBER: DATE:

S.I. #

Snag/ Punch list No.

Description of the Deficiency Issued Date Issued By Expected Time of

Completion

Confirmed By Commissioning

Personnel Remark

Commissioning Eng. Project Management Eng. Contractor

Name: Name: Name:

Signature: Signature: Signature:

Date: Date: Date: To be filled by the Contractor



ATTACHMENT NO. 7

CATEGORIZATION OF THE PUNCHLIST CONTRACT #:

PROJECT TITLE: DATE:

S/S NAME/NUMBER :

S.I. #

Snag/ Punch list No.

Description of the Deficiency

Type of Deficiency

“A” or ”B”

Issued Date

Issued By Date to be

Completed by the Contractor

Remarks

“A” means item to be cleared by contractor prior to Project Energization. “B” means Expected Time of Completion (ETC) to be provided by Contractor/ Project Management Department (PMD); It does not affect Energization.

Commissioning Eng. Project Management Eng. Contractor

Name: Name: Name:

Signature: Signature: Signature:

Date: Date: Date: To be filled by Commissioning engineer/technician prior one month from the Energization.



ATTACHMENT NO. 8

PRE-COMMISSIONING TIME UTILIZATION STATISTIC SHEET COMMISSIONING SERVICES DEPARTMENT

Contract No.: Project Title: Substation Name/Number: Date:

Time Lost Remarks Time Spent by Comm.

Personnel SEC Contractors Sr# Initial

By Date

From To Hrs

Description of the Job

Time Lost Hrs.

CSD PMD SOD Others Test

EquipStaff

Exper. Staff NA

Others

* To be filled by SEC Commissioning engineer/technician. Legend: CSD: Comm. Services Department PMD: Project Management SOD: System Operation



ATTACHMENT NO. 9

UNCONTROLLABLE PROJECT DELAY

Extra Pages: Date Issued by CSD: Contract No.: Project Title:

Elongation Event Code:

Project Time:

Commissioning starting date Event starting date

Event Clearing date

Duration (Day)

ELONGATION PERIOD (Day): 63 days

ELONGATION EVENT REASON AND DURATION

Starting date

Completion date

Period (Day)

Previous %

Current %

Total %

CONTRACTOR

SCADA

OUTAGE PROJECT MANAGMENT

OTHER

DESCRIBTION OF ELONGATION EVENT:

Comments: Division: Division Manager Name Division Manager Signature Date: ____________ ______________________ ___________


TRANSMISSION CONSTRUCTION STANDARD TCS-P-105, Rev. 01PART I: ORGANIZATION OF THE WORK SITE FOR PRE-COMMISSIONING

ATTACHMENT NO. 10

TECHNICAL PROBLEM REPORT

FIL

LE

D B

Y F

IEL

D S

TA

FF

Project Title: Problem Description :

Problem Consequences : Previous History : Attachment : Detail Report Drawing Others

ISSUED BY :

Signature :

ISSUED DATE :

ACCEDED BY :

Commissioning Division Manager

Signature :

ACCEDED

DATE :

FIL

LE

D B

Y T

SC

D

Problem Classification:

Design Material specifications Implementation OTHERS

Recommendation & Solution :

Division Manager Name

Division Manager Signature Date



ATTACHMENT NO. 11

CONFIRMATION OF APPLIED FINAL SETTINGS


Substation Report #


PAGE NO. 35 OF 241

Test Results Approved Setting Details

SL Relay & Serial No. Panel / Circuit

Setting Applied (Visual

Inspection) Final Trip

Remarks Final Setting Issue no. Date

1

2

3

4

5

6

7

Engineer Date Signature

Setting Confirmed


ATTACHMENT NO. 12

FINAL PRE-COMMISSIONING REPORT


S/S NAME/NUMBER

The following items have to be confirmed at the end of the pre commissioning tests:

ITEMS YES NO N/A

Categorization of the punch list (A, B)

Site Tests Completion.

Complete Site Test of HVAC and Energized.

Complete Site test of Station Service Transformer and Energized.

Marked up drawings are available at site in good condition

Operational Spare Parts are provided

Tests Results are available

Emergency contact list is provided

Further Remarks:

Issued by Commissioning engineer/technician

Signature:

Name:




ATTACHMENT NO. 13

READINESS OF ENERGIZATION REPORT

COMMISSIONING SERVICES DEPARTMENT Date Initiated: Extra Pages : Date Received: Contact No: Project Title:

o Facility Name/Number :

o Equipment Name (s) /Number(s)

We have checked the subject project related activities and verified status of conformance to the mandatory requirements that are shown below and list below our findings and comments.

Mandatory Requirements & Conformance Status

o Marked up drawings have been completed o The final Relays Settings have been applied, its test results have been signed and print

out of all final settings for all digital relays have been available. o All Tests Results Sheets are available o Punch-list items of Status A (require modification or shutdown) have been cleared. o SOE Report is received. o Operational and maintenance manuals are received. o Final Trip Tests (through the relay contact) conform.

Comments: Commissioning head engineer.

Project Management Rep.

Contractor site manager

Name: Name: Name: Signature: Signature: Signature Date: Date: Date: Conclusion: Agree to Energize Do Not Agree to Energize unless the following tasks are completed

Division Signature:

Division Manager Name Date:




ATTACHMENT NO. 14

COMMISSIONING TIME REDUCTION AGREEMENT

Agreement to Reduce Time of Pre-Commissioning (Optional)

AGREEMENT BETWEEN SEC AND CONTRACTOR TO REDUCE PRE-COMMISSIONING TIME FOR _____________PROJECT

UNDER CONTRACT NO. ________________

Date & Place: _________________ In order to reduce pre-commissioning time for __________Project, the following agreement is being made between SEC and the contractor. 1. Site Conditions

The following shall be ensured at site before start of SEC witnessing:

a. Testing area is free from all construction activities. b. There is no safety hazard in the testing area and its vicinity. c. Stable auxiliary supply is available for testing purposes. d. Adequate cooling/heating arrangement as the case may be, is available in the control room. e. Adequate lighting is provided to safely carry out the testing activities.

2. Tools and Equipment

All the tools and equipment with valid calibration certificate shall be available at site. 3. Documents

The following documents shall be available at site before start of SEC witnessing:

a. Approved drawings bearing very clear name and signature of the approving authority with approval stamp on each sheet along with complete approval correspondence.

b. The manuals giving detailed test procedure of each equipment, technical data of all electrical equipment, factory test records of all equipment, cable schedules, equipment interconnection wiring schedule and wiring tables/diagrams.

c. SEC approved test procedure and test formats carrying approval stamp with name and signature of the approving authority.

d. The project specifications and protection requirements. e. List of deviations from SEC specs and SEC approval letters for the same.

4. Relay Settings

a. The contractor shall submit his proposed relay settings for all settable relays one month before starting of pre-commissioning witnessing.




b. SEC-Engineering Protection Division shall provide final approved settings before pre-commissioning witnessing is started.

c. Pre-commissioning witnessing will not be started in the absence of approved relay settings, in order to avoid re-setting.

d. Commissioning Program. e. Overall testing commissioning program indicating requirements of Protection, Testing,

Operation, Maintenance and SCADA witness engineers with duration shall be furnished to SEC for approval.

f. A three-week testing program based on the approved overall program shall be submitted every Tuesday indicating the proposed activities for the following two weeks and this program will indicate activities completed in the current week and the reasons for not completing any planned activity and its impact on the overall program with proposed remedial measures.

5. Pre-commissioning Procedures

Pre-commissioning of all equipment shall be carried out in line with SEC Pre-commissioning Procedure and in line with this agreement.

6. Testing and Commissioning Engineers

a. Availability of qualified commissioning personnel to perform pre-commissioning tests. b. One Commissioning Engineer from the contractor shall control the site activities and

doing all required coordination. 7. Tests to be Done by the Contractor

The contractor shall demonstrate a sample test for each equipment mentioned under (I-V) according to the approved test procedure in presence of SEC-Commissioning Personnel and record the results on the approved test format. After approval of test results the contractor can complete the tests of the remaining equipment under (I-V) accordingly without SEC present, witnessing by SEC engineer will be as sample check described in Sample Witnessing by SEC below. I. Secondary injection of all the aux. Relays, MCBs, Timers and O/C or E/F relay. II. CT’s magnetic curves. III. AC/DC Distribution boards. IV. All VTs. V. The contractor shall prepare the detailed test procedure and format to perform the

functional tests.

The contractor shall carry out on his own 100% functional tests for all relay panels, control panels, LCCs, AVC panels and transformer-marshalling kiosk etc. The tests shall ensure the following:

a. Healthiness of all wiring. b. Each wire has correct ferrules as per SEC Standard. c. All wires are correctly terminated. d. The required number of spare terminals has been provided for each terminal block.





e. Required number of spare annunciator windows is available on the control and LCC panels.

f. The accessibility to every equipment terminal is maintained. g. Complete DC isolation for both protection schemes. h. Every abnormality in the substation is indicated in the form of annunciator, relay

flag, LED or lamp, etc. i. Voltage rating of all indicating lamps is 25% higher than substation DC supply. j. All wires are properly identified. k. All DC functional checks and the test results for the same shall be tabulated in special

formats and this format shall include the following items:

i. The name of relay/equipment under operation. ii. The flag or LED appeared on any main or auxiliary relay. iii. Circuit breakers tripped. iv. Auto-re-closing and auto-reclose blocking functions, etc. v. The annunciator on the control panel. vi. Alarm in interface marshaling kiosk. vii. Inter trip send to the remote end. viii. Inter trip received at the remote end. ix. All the above-mentioned functions shall be added as per scheme expectation

and the checking shall be indicated by a tick () mark.

VI. The contractor will use yellow color to indicate the schemes, which have been checked, red color for addition and green color for deletion.

VII. The contractor shall prepare detailed test record for all the equipment mentioned under (I –IV) and submit to SEC.

VIII. The contractor shall prepare detailed test record for all the functional tests mentioned under V. and submit to SEC.

IX. The contractor will be fully responsible for all the above-mentioned tests under (I-V) in all respects. If the contractor fails to carry out these tests properly, he will re-test all these under 100% SEC witnessing.

X. The defective equipment if any shall be logged by serial number and location / designation number and will be promptly replaced.

XI. The protection scheme and control problems shall be cleared from problems to present them for witness

XII. Three sets of marked up drawings with all the modifications incorporated in red color for addition, green color for deletion and yellow color to indicate the checked scheme will be made available before starting witnessing.

Sample Witnessing by SEC

a. The SEC witnessing personnel will select 20% of the equipment covered under I-IV

and the contractor will test all this equipment under SEC witnessing. SEC commissioning personnel will sign only those test results which will be done under his presence.

b. SEC witnessing engineer/technician will do sample test by 20% of each type of panels with minimum of 1 of each type. The contractor will carry out all the functional tests as mentioned under V for these sample-selected panels under witnessing of SEC commissioning personnel. SEC engineer will sign only those test results, which will be done under his presence. SEC engineer has the right to




witness complete bay in respect of all panels, i.e., LCC, relay and control panels, etc.

8. 100% Witnessing by SEC The following tests shall be 100% witnessed by SEC:

a. Secondary injection of all main protection relays except O/C and E/F relays. b. Auxiliary or lockout relays used as trip relays. c. Final settings of all substation timers. d. All indicating and recording meters. e. All transducers. f. Primary injection and stability and sensitivity test of all unit protections, i.e., BBP,

transformer differential and REF protection and underground cable protection, etc. g. Final trip tests, closing tests, SCADA alarm tests. End to end tests, operation and

interlock checks and on-load tests, etc. h. All tests relating to the fault recorder. i. RCT, CT insulation, Lead resistance, CT polarity and Single Point Grounding. j. VT polarity, VT ratio and VT circuit. k. All tests relating to GIS, switchgear, auxiliary transformers, power transformers,

underground cables and battery and battery chargers. l. AC/DC changeover and supervision scheme tests. m. All tests relating to signaling equipment. n. High voltage tests relating to GIS, transformer and underground cable, etc. as

applicable. 9. Snag Rectification, Drawing Updating and Test Record:

a. The contractor will promptly attend to all of the snags. b. Every effort will be done to achieve the goal of “Snag Free Energization”. c. Three sets of the drawings shall be regularly updated with all the modifications

effected from time to time during pre-commissioning. These modifications will be done in red color for addition and green color for deletion.

d. Three sets of marked up drawings; O & M manuals and test records shall be available just before energization of the substation. One set will be kept in a pad-lockable cupboard at the substation, the 2nd one will be handed over to Transmission Department for the office and the 3rd one will be taken by the contractor to prepare the final as built drawing.

10. Signing of Testing Record/Snag Clearance

a. The test record formats will be duly signed by the contractor’s testing engineer and SEC Commissioning personnel simultaneously at the completion of formats for any test. No formats shall be left unsigned for signing next day for quite obvious reasons.

b. SEC Commissioning personnel shall clear the snags after confirming satisfactory completion and such clearance shall not be deferred to a later date in any case.



11. The contractor will submit complete test record to SEC. This test record will include all the tests conducted by the contractor on his own and all those tests conducted by him under SEC witnessing.

12. This agreement can also be applied by the contractor to other substations under the same

contract. 13. This agreement will be considered null and void at the end of Contract No. _________ and

the contractor will have to make a fresh agreement for any other contract/substation in the future.

For SEC

For Contractor Names Signature Names Signature

PMD CSD

Contract No.

Project Title.

Date:



ATTACHMENT NO. 15 CHECK-LIST

ITEM DESCRIPTION DONE REMARKS 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17.

For SEC

For Contractor Names Signature Names Signature

PMD


CSD


ATTACHMENT NO. 16

Contractor’s Performance Report COMMISSIONING SERVICES DEPARTMENT

Contract No. رقم العقدContractor Name. اسم المقاول

Project Title. اسم المشروع

Substation Name/Number: أسم المحطة

تقييم أداء المقاول بوضع دائرة حول الرقم المناسبEVALUATE THE CONTRACTOR’S PERFORMANCE BY CIRCLING APPROPRIATE NUMBER


CATEGORY جيد جداVERY GOOD

جيدGOOD

مقبولSATISFACTORY

يحتاج لتحسين

NEEDS IMPROV

.

غير مرضيUNSATISFACTO

RY الفئة

QUALITY OF THE WORK

25 21 19 15 11 جودةالعمل

AVAILBILTY Of QUALIFIED TESTING ENG.

22 19 16 13 10 تواجدآفاءة

المهندسين

PUNCTUALITY 20 17 15 12 9 التزام

بالحضورSAFTEY 15 13 11 9 7 السالمةCOOPERATION

التعاون 5 6 7 9 10

AVAILABILITY OF PROPER TOOLS AND TEST EQUIPMENT

8 7 6 5 4

توفر األدوات وأجهزة

االختبارات

TOTAL POINTS

100-93

92-80 79-68 67-54

مجموع 53-46 النقاط

OVER ALL RATING التقدير العام FURTHER REMARKS مالحظات

)مهندس اختبارات ما قبل التشغيل(قام بالتقييم Evaluated By (Comm. Eng)

SIGNATURE: :التوقيع

NAME : االسم:

DATE : التاريخ:


. Attachment 17

Procedure Improvement Form

Pages Addition

Correction/

Review Elaboration

Item #

From Comments

تدقيق لإلضافة

Toمراجعة ولإلسهاب و التوضيح

Engineer / Technician’s Name: ______________________ Operating Area: _______________________ Number of attached pages: ______________________ This form to be forwarded to the Technical Support & Coordination Division in the Commissioning Services Department



Attachment 18 Fault report

١١٤١١ الرياض ٥٧ب .صمنطقة أعمال الوسطى

مـــراسالت داخلية المملكة العربية السعودية

ENGINEERING & PROJECTS COMMISSIONING SERVICES DEPARTMENT

TECHINICAL SUPPORT&COORDINATION DIVISION

FAULT REPORT 1. Incident Date And Time

Date: / / G Time:

2. Affected Equipments

Equipment name Substation Trip time Restoration time Relays target

3. Incident Description:

4. Conclusion

5. Action Taken

6. Recommendation Name Job Title Section Date Reported By Approved by:


TRANSMISSION CONSTRUCTION STANDARD TCS-P-105, Rev. 01 PART II: MECHANICAL CHECKS, VISUAL INSPECTIONS & ELECTRICAL TESTS

MECHANICAL CHECKS, VISUAL INSPECTIONS AND ELECTRICAL TESTS

1.0 INTRODUCTION

This Procedure describes the minimum tests and checks to be performed during the pre-commissioning stage of SEC Transmission projects. It deals primarily with the pre-commissioning tests to be followed for protection schemes and main equipment such as cables, transformers and switchgear, etc., keeping in view the SEC standard practices for various types of tests. Further, this listing of tests and checks is based on the requirements and recommendations of the latest issue of international industry standards such as IEC, ANSI, etc.

2.0 PURPOSE

The main purpose of this Procedure is to present a list of checks and tests to be performed on transmission equipment. They shall be performed by the contractor and witnessed by SEC Pre-commissioning personnel.

3.0 PROCEDURE FOR TESTING OF MAIN EQUIPMENT

3.0 PROCEDURE FOR TESTING OF MAIN EQUIPMENT 47

49 3.1 Oil Filled Power Transformer53 3.2 Shunt Reactors 56 3.3 Bushings Inspection and Testing57 3.4 Surge Arrestors 58 3.5 Station Service Transformers (less than 2 MVA)60 3.6 Neutral Earthing Resistors.61 3.7 Current Transformers 63 3.8 Potential Transformers 65 3.9 Capacitive Voltage Transformers66 3.10 Coupling Capacitor Voltage Transformer67 3.11 Hybrid/Gas Insulated Switchgear (GIS)74 3.12 Metal Clad Switchgear 78 3.13 Metal Enclosed Bus Duct79 3.14 Indoor and Outdoor Bus Structures80 3.15 Indoor Circuit Breakers 83 3.16 Outdoor Circuit Breakers86 3.17 Disconnect & Grounding Switches88 3.18 Circuit Switchers 89 3.19 LV AC/DC LV AC/DC Board and Circuit Breakers (380/220/127V) 90 3.20 230kV and 380kV XLPE Cables92 3.21 230 kV and 380kV LPOF Cables94 3.22 110kV and 115kV and 132kV XLPE cables96 3.23 110kV and 115kV and 132kV LPOF Cables98 3.24 69 kV XLPE power Cables100 3.25 13.8 kV and 33 kV XLPE Power Cables101 3.26 LV Cables




3.27 Control Cable 102 3.28 Pilot Cables 103 3.29 Overhead Lines 105 3.30 Protection and Control Panels. 108 3.31 Station Batteries 118 3.32 Battery Charger 120 3.33 AC Distribution Panels 121 3.34 DC Distribution Panels 122 3.35 LV AC Auto-Transfer Schemes/Switches 123 3.36 Grounding System 124 3.37 Switchgear Air Compressor Systems 125 3.38 HVAC Systems 126 3.39 Dry Type Transformer 128 3.40 Ring Main Unit (RMU) 129

3.41 Capcitor Bank Test 130 3.42 Capcitor And Associted Reactor (reactor test) 131 3.43 Fire Detection and Protection Systems 132 3.44 Civil Work 133 3.45 Static VAR Compensation System 134

PART II: MECHANICAL CHECKS, VISUAL INSPECTIONS & ELECTRICAL TESTS



3.1 Oil Field Power Transformer

(Standard Reference is: IEC 60076, SEC Transmission Relevant Specifications 53-TMSS)

3.1.1 Mechanical check and Visual Inspection

ITEM DESCRIPTION REMARKS

1. Check the impact Recorder for any abnormal impact during Transportation. 2. Check all components are installed.

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

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

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

6. Check that all groundings are securely connected. (at least two grounding points to main tank are available)

7. Check that the piping to Buchholz relay has proper slop. 8. Check that the tank pressure is positive.( if applicable )

9. Check the valves between the tank and radiator (To be open).

10. Check the HV – LV and Tertiary (if applicable) bushing for any damage and completeness.

11. Check the color and quantity of silica gel in breather and oil pot level.

12. Check phase marking in cable box and it should match with GIS and cables.

13. Check all pipes – hoses and fan protection (not rubber or plastic).

14. Check the vertical – horizontal clearances of live parts to adjacent grounded point to conform standard.

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

16. Perform all of the manufacturer specific checks.

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

18.

Check proper operation of all auxiliary devices as following: a. Tap changer ( upper – lower – out of step and interlock) b. Oil level gauges. c. oil temperature gauges. d. Winding temperature gauge e. OLTC Oil / Gas surge (pressure) relay. f. Pressure relief device. g. Push buttons and indicators. h. Oil sampling port (main tank – OLTC). i. Upper and lower main tank valves. j. Tap changer diverter switch compartment, oil filtering pumps and

filter in good condition (if available). k. Buchholz relay. l. Check on line insulating oil dissolved gas and moisture monitoring

system (if applicable )

19. Check Oil leakage by applying 0.35 bar (35kPa) over pressure for 24 hrs.




ITEM DESCRIPTION REMARKS 20. Check that the oil sampling devices are reachable from ground level 21. Check oil level in main tank, conservator, tap changer tank and bushing etc. 22. Bleed trapped air at the bushing turrets and tank top.

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

24. Check all external wiring for correctness and tightness.

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

26. Check that the temperature sensors oil well is two thirds filled with oil.

27. 33kV Load Break Switch Panel with HRC fuses for 33kV Station Transformer

28. Neutral Grounding Transformer or Reactor

29. Check that the each optical feed through unit is properly connected to the ports of Hot spot temperature measuring device

30. Internal inspection of the transformer before installation of the high side bushing of new transformer in order to inspect the upper yoke for any bents on the core and paint particles found.

3.1.2 Electrical Tests

(Standard reference. IEC 60076, SEC Specifications 53-TMSS)

ITEM DESCRIPTION REMARKS 1. Core Insulation Resistance at 1 kV DC. 2. Winding Insulation Resistance and Polarization Index test at 5 kV DC.

3. Winding Resistance (DC) test ( at all taps ) (winding temperature shall be recorded, winding resistance shall be referred to 75°C)

4. Excitation Current measurements from primary side at each tap by applying 220 or 380 VAC on the HV terminal keeping the LV winding open.

5. Insulation power factor test for oil and bushing at 10 kV ac

6. Polarity, vector relationship and % Impedance test at normal tap

7.

Winding temperature indicator to be calibrated by heating the sensor in oil bath and check against standard thermometer. Also check by current injection, Check pick up/ Drop off of contacts:

- Fan, oil pump, alarm, trip contacts. Proper setting as per drawing to be applied and tested.

8. Oil temperature indicator to be calibrated by heating the sensor in oil bath and check against standard thermometer. Setting as per drawing to be applied and tested.

9. Percentage impedance (Short circuit impedance) test at lower tap, normal

tap and higher tap

10. Turns Ratio ( all taps )





11. Check for current and voltage ratings of all motors for tap changer, oil filtering unit and fans match to SEC standard supply. MCB’s for protection are set at proper over load settings

12. Fan motors current (starting, running, one phase removal and locked rotor) shall be measured and checked against rating .check if wiring size suitable to carry the current.

13. Check fan running direction to get air flow towards radiator and Phase sequence of supply voltage to fan motors circuits is correct.

14. MCBs in marshalling kiosk to be checked by current injection each pole for alarm and trip.

15.

On load Tap Changer checking check current and voltage ratings of tap changer motor

a. Raise / Lower Control (Local – Remote) and indication. b. End of Tap Travel Control. c. End of winding travel control (both ends). d. Check that the windings are not open circuit during tap changing. e. Check OLTC manual operation by hand crank f. Check insertion of hand crank automatically prevent electrical

motor drive operation. g. Check OLTC tap position indicator& operation counter h. OLTC motor load current to be measured for future reference

purposes i. Check all transmitters

16.

Bushing Current Transformer a. Polarity test b. Insulation Resistant test c. Secondary Winding Resistant (All windings and all taps). d. Current Ratio test

Magnetization Characteristics (Minimum 5 points below and 2 points above the knee point.

f. Verify secondary circuits, Terminals to Terminal. g. Burden Test. h. Demagnetize CT cores after all tests. i. Ensure that No open circuit at Secondary side.

17.

Functional Check of the following :- a. Liquid Level indicator (alarm/ trip) as applicable. b. Oil Temperature Device: Fans / pumps (stop, start alarm/ trip) c. Winding Temperature Device (alarm/ trip). d. Buchholz Relay (alarm/ trip). e. Oil / Gas Surge (pressure) relay (alarm/ trip). f. Pressure Relief Device (alarm/ trip). g. Rapid Pressure (Rise) Relay as per manufacturer testing procedure (if

applicable). h. On line insulating oil dissolved gas and moisture monitoring system. i. Humidity/thermo meters for the heater of local panel are at correct

settings.





18.

Insulation Oil Test :per 54-TMSS-01 Prior to energization, contractor should submit test report for insulation sample tested in an independent lab. For the following :

a. Dielectric strength i) ASTM D877 ( 2.5mm Gap ) for unprocessed oil and

for OLTC oil ii) ASTM D1816 ( 1 mm gap )for oil in main tank

b. Neutralization Number ( ASTM D974 ) c. Interfacial Tension ( ASTM D971 ) d. Color ( ASTM D1500 ) e. Moisture Content (ASTM D1533 A) f. Power Factor Test ( ASTM D 924 ) g. Dissolved Gas in Oil Analysis (ASTM D3612) h. (Dielectric Dissipation Factor, Resistivity, Sediment and / OR

Perceptible Sludge). i. For transformer with Cellulosic insulating material, perform

sulfuric contents detection test as per ASTM D1275 method B.

Another oil sample shall be given to SEC transmission for their own analysis and compression purpose

The oil sample should be taken by contractor using syringe from the oil valve.

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.

20. Frequency responses test if the transformer has been severely shocked during shipping. For all transformer frequency response and inrush current test.

21. Zero sequence impedance test

22. Insulation resistance of control wires (1000 VDC for one minute)

23. Magnetic balance test

24.

Oil dielectric test at site: Five samples shall be taken as following; top of main tank, bottom of main tank, OLTC tank, main tank conservator and OLTC conservator, the average result shall not be less than 50kV at 2.5 mm gap.




3.2 Shunt Reactors

(Standard Reference is IEC 60076-6 and relevant SEC Transmission Specifications58-TMSS-01)

3.2.1 Mechanical Checks and Visual Inspections

ITEM DESCRIPTION REMARKS 1. Check the impact recorder for any abnormal impact during transportation. 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 micro-switch. g. Push buttons and indicators. h. Oil sampling port (main tank). i. Upper and lower main tank valves.

20. Check Oil leakage by applying 0.35 bar (35kPa) over pressure for 24 hrs. 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.

23. Bleed trapped air at the bushing turrets and radiators. 24. Check that the each optical feed through unit is properly connected to the

ports of Hot spot temperature measuring device






ITEM DESCRIPTION REMARKS 1. Core Insulation Resistance Test at 1 kV DC 2. Winding Insulation Resistance Measurement Test and Polarization Index

(P.I.) Test at 5 kV DC.

3. Winding Resistance Test. (winding temperature shall be recorded; winding resistance shall be referred to 75°C).

4. Inductance Measurement. 5. Impedance Measurement. 6. Winding temperature device to be calibrated 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 the sensor in oil bath and check against standard thermometer. Setting as per approved drawing to be applied and tested.

8. Insulation power factor test for oil and bushing 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. (alarm / trip) as applicable. d. Buchholz Relay (alarm and trip). e. Pressure Relief Device (alarm and trip) f. Humidity/thermo meters for the heater of local panel are at correct

settings.

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

Sludge).





i. Add Corrosive Sulfur test report 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.

13 Frequency responses test if the reactor has been severely shocked during shipping.





3.3 Bushings

(Standard Reference is IEC 60137 and relevant SEC Transmission Specifications 52-TMSS, 53-TMSS)


1. Cleaning the insulator surface. 2. Check for tightness of all bolts for 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.



3.4 Surge Arrestors

(Standard Reference is relevant is IEC 60099-4 and SEC Transmission Specifications-35-TMSS-01)

3.4.1 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 securely connected. The Grounding Cable size should be checked.

5. Check name plate information for correctness as per SEC 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.




3.5 Station Service Transformers (less than 2 MVA)

(Standard Reference is relevant IEC 60076-1 and SEC Transmission Specifications 51-TMSS-01)

3.5.1 Mechanical Checks and Visual Inspection

ITEM DESCRIPTION REMARKS 1. Check the Impact recorder for any abnormal impacts during transportation (if

applicable).

2. Check for LV Side Air Circuit Breaker before cable at transformer side. If applicable.

3. Check for Danger Plate Warning installation. 4. Check earthing, color, painting, external damage, oil leakage, wheel stopper,

cable connection and bolt tightness, etc.

5. Check nameplate data against contract specifications. 6. Perform all special checks according to the manufacturer’s instructions. 7. Check oil level in HV side cable box and its oil level indicator or HV fuses (if

applicable).

8. Check that the off load tap-changer is set at the nominal voltage tap. 9. Check all devices are labeled correctly as per drawing.



1. Check LV side MCCB setting as per transformer current rating 2. Ratio Test (all taps), Insulation resistance measurement test on all windings and

polarization index (P.I.) test. test at 5kV DC

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). (Oil temperature shall be recorded; winding

resistance shall be referred to 75°C).

10. Back energization test at rated voltage for 15 minutes. 11. Perform functional tests of all auxiliary devices (as applicable ) 12 Oil dielectric test at site shall not be less than 50kV at 2.5 mm gap. 13. 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) 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. The oil sample should be taken by contractor.




3.6 Neutral Earthing Resistors.

(Standard Reference is ANSI/IEEE std 32 and relevant SEC Transmission Specifications 57-TMSS-01)

ITEM TEST DESCRIPTION REMARKS

1 Check nameplate data against contract specifications. 2 Check the value of resistance and current ratings against the specifications.

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

4 Test on NER HV side associated CT & power cable. 5 Inside visual inspection for any insulator broken. 6 Main circuits Resistance measurement test.

7 Insulation resistance measurement test. at 5kV DC >=1000meg

aohms 8 Cleaning of all internal as well as external to NER before energization. 9 Check identification and function of NER isolator (if applicable).

10 Check that the enclosure earth terminal and resistor earth terminal are separate to allow the possibility of disconnection during testing.

11 Check the grounding resistance of the enclosure earth terminal and resistor earth terminal.

< 2 ohms




3.7 Current Transformers

(Standard Reference is IEC 60044-1 and relevant SEC Transmission Specifications 50-TMSS-01, TES-P-119.28)

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 according to SEC specification (ring type lugs).

8. Check CT locations physically and secondary terminal labeling has been done correctly.



1. Magnetizing current test 2. Winding resistance measurement. (Ambient temperature shall be recorded;

winding resistance shall be referred to 75°C).

3. Polarity test or flick test with battery. 4. Ratio test by current primary injection. 5. Insulation resistance test, as following:

a. Primary to ground 5kV DC for one minute. b. Primary to secondary 2.5kV DC for one minute. c. Secondary to ground and core to core 1kV DC for one minute.

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

injection of CTs. Installation of ct direction is as per the approved drawings and required weather proof labels are available, and check single point earth for each CT circuit.

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. In case of LV/MV switchgear The in/out movement of VT





Trolley is smooth and no excessive efforts are required. 11. Test inter-core coupling for all bus differential CTs. 12. NOTE: During stability test of power transformer, test all BCT's (bushing

current transformers). That means primary injection test, turns ratio, check secondary circuits related to BCT by checking short & isolate facility, measure currents at each point of all loops and compare between measured values and expected values.

13. Note: It is necessary to demagnetize the cores before each test,




3.8 Potential Transformers




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.

7. Check integrity of primary fuses (if applicable). 8. Check insulation liquid level and leakage (if applicable). 9. Make sure that MCB for VT secondary is provided in the VT box. So that the

secondary cable up to LCC is protected

10. Gas leakage check for GIS VTs compartment


ITEM DESCRIPTION REMARKS 1. Winding Resistance Test. (Ambient temperature shall be recorded; winding

resistance shall be referred to 75°C).

2. Insulation test as following: Primary to ground 5kV DC for one minute. Primary to secondary 2.5kV DC for one minute. Secondary to ground and core to core 1kV DC for one minute.

3. Ratio Test. 4. Polarity Test. 5. Primary and secondary fuses rating checks for (if applicable). 6. Ensure VT is included in switchgear and GIS high voltage test. Test

voltage is 1.5Uo (where Uo

is -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.




ITEM DESCRIPTION REMARKS 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. Capacitance and dielectric dissipation factor (tan ), this test apply only to

transformers with liquid immersed primary winding insulation for 110 kV and above

TABLE 1

SYSTEM

RATED

VOLTAGE

(KV)

RATED LOAD

FACTOR TEST VOLTAGE

(KV) FREQUENCY TIME PERIOD REMARKS

11 1.5 9.5 13.8 1.5 12

33/34.5 1.5 28 69 1.5 60 110 1.5


95

I Minute

These tests are applicable to

electromagnetic VT’s

60 Hz 115 1.5 99.5 132 1.5 114 230 1.5 199 380 1.5 329



3.9 Capacitive Voltage Transformers




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. Make sure that MCB for VT secondary is provided in the VT MK. So that the


10. Check drain coils (if applicable). 3.9.2 Electrical Tests


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).



3.10 Coupling Capacitor Voltage Transformer




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. Make sure that MCB for VT secondary is provided in the VT MK. So that the


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


ITEM DESCRIPTION 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.




3.11 Hybrid/Gas Insulated Switchgear (GIS)

(Standard Reference is IEC 62271-203 and IEC 62271-205 and relevant SEC Transmission. Specifications 32-TMSS-02 and 32TMSS-04)

3.11.1 Mechanical Check and Visual Inspection

ITEM Description Remarks

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 oC or lower.

15. Gas leaks 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 have definite mark scale.

18. Check the gauges are ambient Temperature compensated.





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

20. Check all wiring is colored according to approved drawings and specifications.

21. Verify that all front panel mounted devices (meters, push buttons, switches, indicator lamps, mimic buses, etc.) are installed as per drawings, fixed permanently and are correctly labeled.

22. Verify that all operating devices are correctly labeled.

23.

Perform mechanical checks and visual inspections on all component equipment: Circuit breakers. Current transformers. Voltage transformers. Disconnect and grounding switches.

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

25. Ensure that all disconnects switches are provided with viewing windows or mechanical indicators for verification of contact positions and that all grounding switch positions can be visually verified from ground level.

26. 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 zone marking plates fixed over the gauges.

28. Check & confirm GIS VT’s primary isolation device with manual operation provided, along with it monitoring system locally as well as on mimic diagram in control room.

29. For hydraulic mechanisms the hydraulic system to be checked and assure that no leakage.

30. Check & confirm the three-phase test adaptor and bushing for HV test on GIS have been provided.

31. Check & confirm there are no any sharp edges for the cable trays or other metallic parts.

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

3.11.2 ELECTRICAL TEST


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 (CB’s, disconnect, etc.) in a closed position.

6. Check contact resistance separate test for CB and all DS.& ES

7. Functional check of all alarms, interlocking and indication circuits from the GIS to the local control cubicle.

8. CB’s, DS’s and ES’s Timing Test (Open & Close) with contact travel and speed analysis.

9. 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.

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

11.

GIS PTs to be included during AC HV tests on GIS when test frequency is well above rated Frequency, otherwise test at 1.5Un – one minute at rated frequency without secondary load. PTs secondary out put volts shall be measured accordingly during the high voltage test.

12. All AC/DC MCBS shall be tested by trip test through current injection in each pole.

13. Measure current drawn by motor for CB and DS and check the results according to design.

14. Check VT HV neutrals externally available especially in case of VTS installed directly on cable feeder.


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

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

18.

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.

19. Functional test of trip free and anti pump circuits

20. Check Minimum control voltage trip (60%) and close (80%) operations.




ITEM Description Remarks 21. Check spring charge time and motor currents at rated control voltage.

22. Functional checks of breaker operation counter.

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

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

25. Calibrate the metering devices such as ammeter, voltmeter…

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




HV Tests on Gas insulated switchgear (GIS)

Preparation for HV test

1. The GIS shall be installed completely and gas-filled at its rated filling density. 2. The HV may be produced by:

- Test sets with a test transformer, - Test sets with a variable resonant reactor for constant frequency, - Test sets with constant resonant reactor for variable frequency, - Energizing power or voltage transformers from the low-voltage side which entails no

dismantling after testing. 3. Some parts may be disconnected for the test, either because of their high charging current or

because of their effect on voltage limitation, such as - High voltage cables and overhead lines; - Power transformers and, occasionally, voltage transformer. - Surge arresters and protective spark gaps.

4. Every newly installed part of a GIS shall be subjected to HV test on site. 5. In the case of extensions, in general, the adjacent existing part of the GIS should be de-

energized and earthed during the HV test. 6. In extension projects due to practical reasons of joining new and old GIS together, the test

may be performed at reduced voltage level for an extended duration , or soaks the GIS (after joining old with new GIS) for 24 Hours at rated voltage. The above is subjected to agreement between SEC and supplier and depending on the site conditions.

7. The HV test shall be distinguished by their progressive voltage increase, performed in order to achieve some form of electrical conditioning of the equipment before commissioning.

8. The term electrical conditioning means a progressive application of an AC voltage either by steps or continuously according to the manufacturer’s recommended test procedure. It may be performed by the manufacturer as part of the gas-filling process on site in order to move possible particles towards areas with low field strength, where they become harmless.

9. Electrical conditioning is not requirement and does not replace the AC voltage test, unless the test voltage is increased up to the specified value. Nevertheless, a disruptive discharge should be reported to the user as it may result in weakening of the insulation.

10. The HV voltage tests are especially sensitive in detecting contaminations (e.g. free moving conducting particles), and are, in most cases, also sufficient in detecting abnormal field configurations.

11. It is often convenient to divide the whole installation of GIS into sections by opening circuit breakers and/or disconnectors for at least one of the following reasons:

- To limit the capacitive load on the test voltage source. - To facilitate the location of disruptive discharges. - To limit the discharged energy if a disruptive discharge occurs.

12. For 3-phase enclosed GIS, the specified test voltage shall be applied between each phase conductor, one at a time, and the enclosure, the other phase conductors being connected to the earthed enclosure. The insulation between phase conductors shall not be subjected to any other separate HV test on site.

13. All CT's secondary winding should be short circuited during the test and grounded. 14. Before the HV test the contractor should measure the PD level and record it and; at the end

of the test; subtract this value from the result (if applicable and possible to be performed).

Test procedure




The capacitance current (mA) should be measured at all voltage steps and compared with the estimated value. Estimated value of capacitance current = V 2 π f C V: the test voltage (V). F: the frequency of the applied voltage (Hz). C: the capacitance of GIS (get from the manufacturer) (F).

Procedure A (recommended for 170kV and below)

- Electrical conditioning (depend upon the manufacturer) - HV test for a duration of 1 min. at the value specified in the table no. ( 1 ) - Partial discharge measurements according to table no. (2) When

decreasing the HV. Procedure B (recommended for 245kV and above)

- Electrical conditioning (depend upon the manufacturer). - HV test for a duration of 1 min. at the value specified in the table no. ( 1 ) - Partial discharge measurements according to table no. (2) When

decreasing the HV.

Procedure C (recommended for 245kV and above, alternative to procedure B):

- Electrical conditioning (depend upon the manufacturer). - HV test for a duration of 1 min. at the value specified in the table no. ( 1 ) - Lightning impulse tests with three impulses of each polarity and with the

value specified in table no. (1).

Assessment of the test

- The switchgear shall be considered to have passed the test if each section has withstood the specified test voltage without any disruptive discharge.

- The partial discharge measurements within the limits (10 pC). - In the event of disruptive discharge occurring during dielectric tests on site, the test shall be

repeated.

Repetition tests The procedure to be implemented following a disruptive discharge during dielectric tests on site may depend on several factors which include:

- The type of disruptive discharge (breakdown in self-restoring or non-self-restoring insulation).

- Magnitude of the arc energy dissipated during the discharge. - Shape and material of the solid insulation.

Consideration of these and any other relevant factors should allow a procedure to be established and agreed between the manufacturer and SEC.




Table No. (1): On site test voltage (IEC 62271-203 @ 2003-11)

No. Rated voltage for GIS (Ur )

kV

On-site short duration power frequency withstand test ( Uds) 1 min

kV

On-site lightning impulse withstand voltage ( Ups) kV

1 72.5 120 260 2 100 165 360 3 123 200 440 4 145 235 520 5 170 270 600 6 245 380 840 7 300 380 840 8 362 425 940 9 420 515 1140 10 550 560 1240

Table No. (2): On site partial discharge measurement (IEC 62271-203 @ 2003-11)

System with solidly earthed neutral System without solidly earthed neutral

Rated voltage for GIS (Ur )

kV Pre-stress voltage

( 1 min) kV (HV test )

Test voltage for PD measurement

( > 1 min) kV 1.2 Ur / √3

Pre-stress voltage

( 1 min) kV (HV test)

Test voltage for PD measurement ( > 1 min) kV

1.2 Ur

1 123 200 85.21 200 147.6 2 145 235 100.45 235 174 3 245 380 169.74 380 294 4 420 515 290.9 515 504

Maximum permissible value for partial discharge is 10 pC The procedures that should be done after the HV test finished successfully:

Put all voltage transformers in service. Apply the rated voltage to the GIS. Measure all voltage transformers secondary winding voltage in the Local control panels in

GIS switchgear. Increase test voltage at (Vf * Ur) for 1 minute which :

Vf = voltage factor Ur = rated voltage Test sheet may be as follows:

Test voltage

Test time

Capacitance current (mA)

Partial discharge measurement (pC)

kV Hz Min. Phase

A Phase

B Phase

C Phase

A Phase

B Phase

C

remarks

Electrical conditioning*

Test voltage Electrical conditioning* Partial discharge voltage *Electrical conditioning steps depend upon the manufacturer.




3.12 Metal Clad Switchgear

(Standard Reference is IEC 62271-100 and relevant SEC Transmission specifications 32-TMSS-01) 3.12.1 Mechanical Check And Visual Inspection


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 of dust accumulation.

10. Check main and riser buses for correct phasing connections.

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 check and visual inspection on all circuit breakers. 13. Perform mechanical check and visual inspection on all current transformers. 14. Perform mechanical check and visual inspection on all voltage transformers.

15. Perform mechanical check and visual inspection on all disconnected 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.

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. 26. Verify that correct Dispatch Numbers have been installed.

27. Check that all special tools, devices, etc., as per specification have been provided.

28. Check existence of warning signs according to SEC specification





(Standard Reference is IEC 62271-100 and relevant SEC Transmission specifications 32-TMSS-01)


1. Insulation resistance test of all wiring, cabling and auxiliary circuit in the panels.

500 V DC


3. Bus continuity and phasing test.

4.

Main circuit resistance test with the switchgear erected but not yet connected to the cables. Perform with 100 ampere DC by micro-ohmmeter from panel to panel on each phase from cable spouts with all circuit breakers racked in service and 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 reference (at standard temperature)

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

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

7.

Perform electrical tests on all component equipment as per SEC approved procedures: Circuit breakers. Current transformers. Voltage transformers. 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. Contact resistance separate test for CB and all DS.

10. Functional test of all electrical interlocks.

11. Functional test of trip free and anti pump circuits.

12. Functional test of local, alarm and indications.





13. Functional test of remote, alarm and indications.

14. Minimum control voltage trip and close operations.

15. Check and test capacitor trip circuit (if applicable).

16. Check spring charge time and motor currents at rated control voltage.

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


19. Timing test open/close using an electronic oscillograph.


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



3.12.3 Guidelines for High Voltage Test on main circuits including CBs

a. Preparation and precaution before HV test b. For vacuum breakers, test across open contact and live parts to ground.

Precautions should be taken against emission of X-rays. c. For all other breakers. Test in conjunction with breaker racked in the

switchgear and in the closed position. The following shall be observed:

a. The new switchgear not connected yet to cables should be tested as a whole

unit with all circuit breaker in close position. b. All back shutters must be closed. c. Gas Pressure indication for the circuit breaker should be checked under

permissible limits. d. VTS, cables or any other voltage indication should be in out position and

VTS secondary side fuses should be taken out. e. CTS secondary terminals should be short-circuited and earthed. f. 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. g. 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. h. Charging current for each test is noted and recorded. i. HV Test is considered successful if no breakdown occurs during test period. j. HV Test levels and time for pre-commissioning testing of switchgear are

given in Table 2.




AC High Voltage test

a. Voltage shall be applied on each phase with all other phases and then frame

grounded. b. Test shall be performed with the CB in both the closed and open position. c. In open position, the cable contacts are to be grounded. d. Test voltage levels are given in Table-2 below. e. After the high voltage test on main circuit is finished, rack the voltage

transformers in service position and apply on primary side a test voltage 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.

f. Make sure the VTS secondary side MCBS are switched off and any resistor in open delta winding should have been removed.

g. Compare the observed ratio with actual ratio. h. HV Test should be repeated with circuit breakers in open position keeping

cable spouts in earthed condition in all panels.

T A B L E – 2

TEST VOLTAGE LEVEL FOR MEDIUM VOLTAGE METAL CLAD SWITCHGEAR

Switchgear Ratings

AC Test Voltage Time Period

11KV

25kV 60 Hz

60 Sec

13.8 kV

30 kV 60 Hz 60 Sec

33 & 34.5 kV

56 kV 60 Hz 60 Sec




3.13 Metal Enclosed Bus Duct

(Standard Reference is relevant SEC Transmission Specifications-TES-P-119.09)



1. Inspect for physical damage or defects. 2. Check bus arrangement for conformance with approved drawings. 3. Check tightness of all bolted connections (torque wrench method). 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.




3.14 Indoor and Outdoor Bus Structures

(Standard Reference is relevant SEC Transmission Specifications- TES-P-119.09)


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


ITEM DESCRIPTION REMARKS 1. Measure resistance of bus section joints at 100 A DC. 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).




3.15 Indoor Circuit Breakers

(Standard Reference is relevant SEC Transmission Specifications, 37TMSS) 3.15.1 Mechanical Checks and Visual Inspections

ITEM DESCRIPTION REMARKS 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: 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,

and 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. 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).




ITEM DESCRIPTION REMARKS 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, and

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.



ITEM DESCRIPTION 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 checks 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 motor/spring operating mechanisms, measure spring charge time and Measure motor starting and running 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. Checks the correct functioning of interlocks and limit switches.




3.16 Outdoor Circuit Breakers

(Standard Reference is relevant SEC Transmission Specification 37-TMSS) 3.16.1 Mechanical Checks and Visual Inspections


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.



10. For pneumatic operating mechanisms: a. Check the compressor, air piping, valves, pressure gauges, air filter,

water trap and switches for damage or defects. b. Calibrate the air pressure gauges. c. Check the setting of air pressure switches (compressor start/stop, alarm,

and 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. 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).

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, and

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.


ITEM DESCRIPTION REMARKS 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



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.

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.




ITEM Description Remarks 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.




3.17 Disconnect & Grounding Switches

(Standard Reference is relevant SEC Transmission Specifications30-TMSS-01)

3.17.1 Mechanical Check And Visual Inspection

ITEM Description Remarks 1. Inspect for physical damage and 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, CB’s, etc.). 16. Check that the operator’s platform is of adequate size and is properly

grounded.

17. Check mechanical alignment and contact gap "if applicable"



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


3. Measure motor starting and running current.

4. Check position-signaling contacts (if applicable).

5.

For motor operating mechanisms: a. Check mechanism cabinet grounded. b. Check correct setting of motor limit switch (open/close). c. Check correct operation of all auxiliary “a” and “b” contacts. d. Measure switches 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 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.

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




3.18 Circuit Switchers

(Standard Reference is relevant SEC Transmission Specifications37-TMSS-01 and 37-TMSS-02)



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.



1. Resistance of main current path (terminal to terminal) at 100 Amps DC. 2. Functional check of all electrical interlocks. 3. Measure motor starting and running current. 4. Check position-signaling contacts (if applicable). 5. 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 switches 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.

6. Check shunt trip device operation. 7. Verify proper operation sequence of interrupters and disconnects. 8. Insulation power factor test of the interrupters. 9. Timing test of the interrupter contacts with electronic oscillograph.




3.19 LV AC/DC LV AC/DC Board and Circuit Breakers (380/220/127V)

(Standard Reference Is IEC 60947-2 and Relevant SEC Transmission Specifications 37-TMSS-03 and 31-TMSS-02)


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

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

3. Phasing check.

4. Check & verify for all MCCBs ratings as per requirement.

5. Single pole Trip Test of all MCBs by current injection as per manufacturers given curve.

6. All Ampere & Volt meter to be calibrated.

7. Insulation Test on all Secondary wiring & cables.

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

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




3.20 230kV and 380kV XLPE Cables

(Standard Reference is IEC 62067 and relevant SEC Transmission Specifications 11-TMSS-02, Rev. 0 and TCS-P-104.01, TCS-P-104.02, TCS-P-104.03, TCS-P-104.06 and TCS-P-104.08)


ITEM Description REMARKS

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 Check/inspect the cable outer jacket for any physical damage or irregularities.

8 Check/inspect the transposition of cable phases

9 Check for the cross connection of cable metallic sheath in cross bonding system

10 Check the rubber seal in the cable clamps to avoid any damage to cable outer jacket

11 Check the insulating shrouds are installed at the base of cable terminations

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

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

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

15 Check that phases are identified and color coded

16 Single Core Cable connected between Power Transformer and SWGR shall be single point earthed at SWGR side and at floating side SVL (sheath voltage limiter) should be installed.

17 Check Single point or both ends, via voltage limiter as per approved design.

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

19

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

20 Check irregularities of outer jacket formed by non uniform shield wire distribution.




3.20.2 Electrical Test

(Standard Reference is IEC 62067 and relevant SEC Transmission Specifications)


1 Phase checking for conductor & sheath bonding. 2 Conductor resistance, Capacitance and inductance measurement test

3 Sheath DC high voltage test (10kV DC for 1 min.) and 5 kV DC insulation tester before and after high voltage/ 24 hour Soaking test.

4 Anti corrosion sheath test

5 Measure the ground resistance at all link box positions

< 2 Ω located inside substation <10 Ω if located far from substation)

6 Zero and positive sequence impedance measurement 7 SVL (Sheath voltage Limiter)test By2.5kV DC insulation tester 8 Insulation resistance test of cable by 5kV 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 profile test.

13 Measurement of grounding resistance of all link boxes shall be as per SEC standard TES-P-104.08

14 Contact voltage measurement shall be as per SEC standard TES-P-104.08 15 In case of Double Circuit (110kV & above), check the separate grounding pit

16

AC High voltage test for all new cables, but if old portions are involved then soaking for 24 hours at rated voltage. (For equipments/cables projects, where old portion is involved, the decision to apply HV testing shall be decided by the mutual agreement between SEC and Contractor.)

For HV Test see table 2-1



3.21 230 kV and 380kV LPOF Cables

(Standard Reference is. IEC 60141-1 and relevant SEC Transmission Specifications 11-TMSS-03, TCS-P-104)



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 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, 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.

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

9. Pressure test of all associated oil piping 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. Availability of oil sampling facility valve arrangement. 13. Check Single point or both ends, via voltage limiter as per approved

design

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

15. Oil flow test 16. Impregnation test 17. RGP test / DGA test

18.

For accessories (sealing terminations, pressure tank, gauges, instrument panels and link boxes), check the following as applicable: a. Nameplates installed and data is correct. 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





(Standard Reference is. IEC 60141-1 and relevant SEC Transmission. Specifications)


1. Check Phasing for conductor & sheath bonding

2. Conductor resistance, Capacitance and inductance measurement test

3. Sheath DC high voltage test (10kV DC for 1 min.) and 5 kV DC insulation tester before and after high voltage / 24 hour Soaking test.

4. SVL (Sheath voltage Limiter)test by2.5kV DC insulation tester

5. Anti corrosion sheath test

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

less than 2 Ω for location inside substation <10 Ω for located far from substation

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 profile test

14. Insulation oil dielectric breakdown test and water content test.

15.






3.22 110kV and 115kV and 132kV XLPE cables

(Standard Reference is IEC 60840 and relevant SEC Transmission. Specifications 11-TMSS-02, Rev. 0 and TCS-P-104.01, TCS-P-104.02, TCS-P-104.03, TCS-P-104.06 and TCS-P-104.08)



1 Inspect for physical damage or defects.

2 Check tightness of all bolted connections (torque wrench method)

3 Check for proper cable bolted connections


5 Check for proper cable support ,clamping ,trays Blocking






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 Inspection of label inside link boxes and water proofing test 14 Check cable entry path trench as ducts are to be properly sealed.







21

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

a. Nameplates installed and data is correct. b. Condition of paint work c. All bolted connections





(Standard Reference is IEC 60840, and relevant SEC Transmission. Specifications 11-TMSS-02, TCS-P-104)


1. Check Phasing for conductor and sheath bonding.



4. Conductor insulation resistance test

5. Cross – bonding verification test

Sheath Current < 3 % the Sheath Current should be 3%, the current due to induction of neighboring circuits should be considered and the limit should be 3%+current due to external circuits

6. Zero and positive sequence impedance measurement 7. SVL (Sheath/surge voltage Limiter) test by 2.5kV DC insulation tester

8. Measure the ground resistance at all link box positions

<2 Ω for located inside substation <10 Ω for located far from S/S

9. Contact resistance test on link boxes ( less than 20 µΩ )

10. Metallic sheath continuity test (if applicable)

11. Anti corrosion sheath test 12. Cable profile test

13. Measurement of grounding resistance of all link boxes shall be as per SEC standard TES-P-104.08

14. Contact voltage measurement shall be as per SEC standard TES-P-104.08

15. In case of Double Circuit (110kV & above), check the separate grounding pit

16.

AC High voltage test for all new cables, but if old portions are involved then soaking for 24 hours at rated voltage. (For equipments/cables projects, where old portion is involved, the decision to apply HV testing shall be decided by the mutual agreement between CSD and Contractor.)





3.23 110kV and 115kV and 132kV LPOF Cables

(Standard Reference is IEC 60141-1,-2 -3, and relevant SEC Transmission Specifications 11-TMSS-03, TCS-P-104)



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





9 Pressure test of all associated oil piping 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 Availability of oil sampling facility valve arrangement.


14 Oil flow test 15 Impregnation test 16 RGP test / 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), cheek the following as applicable: a. Nameplates installed and data is correct. b. Link box tightness check. c. Inspection of label inside link boxes and water proofing test d. All valve positions according to design (open/closed). e. Calibrate pressure gauges and pressure switches. f. Oil pressure. g. No oil leaks. h. Condition of paint work i. All bolted connections





(Standard Reference is IEC 60141-1, -2 -3, and relevant SEC Transmission Specifications 11-TMSS-03, TCS-P-104)


1. Check Phasing for conductor & sheath bonding.


3. Conductor resistance, Capacitance and inductance measurement 4. Conductor insulation resistance test


6. SVL (Sheath voltage Limiter) test by2.5kV DC insulation tester


less than 2 Ω for location inside substation <10 Ω for located far from S/S

8. Contact resistance test on link boxes 9. Oil pressure gauge Function test. 10. Shield continuity test 11. Anti corrosion sheath test 12. Cable profile test 13. Insulation oil dielectric breakdown test and water content test.

14.






3.24 69 kV XLPE power Cables

(Standard Reference is. IEC 60840 and relevant SEC Transmission Specifications 11-TMSS-01, TCS-P-104)



(Standard Reference is. IEC 60840 and relevant SEC Transmission Specifications)

ITEM Description REMARKS 1. Check Phasing for conductor and sheath bonding. 2. Conductor resistance, Capacitance and inductance measurement test 3. SVL(sheath voltage limiter)test By 2.5kv DC insulation tester 4. Anti corrosion sheath test


less than 2 Ω for location inside substation

ITEM Description REMARKS 1. Inspect for physical damage or defects 2. Check tightness of all bolted connections (torque wrench method)

3. Check for proper cable bolted connections


5. Check for proper cable support ,clamping ,trays, blocking 6. Link box tightness check




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. Check irregularities of outer jacket formed by non uniform shield wire

distribution.

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






<10 Ω for located far from S/S

6. Zero and positive sequence impedance measurement 7. Insulation resistance test for conductor



10. Contact resistance test on link boxes ( less than 20 µΩ ) 11. Metallic sheath continuity test (if applicable) 12. Cable profile test

13.






3.25 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.

6. Check tightness of all bolted connections (torque wrench method). 7. Check that phases are identified and color coded. 8. Check cable entry path trench as ducts are to be properly sealed. 9. Verification of exact route length as per approved drawings from

termination to termination.

10. 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.(1000v DC insulation resistance) IR for sheath

> 10 Meg-ohms

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 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.




3.26 LV Cables



ITEM DESCRIPTION REMARKS 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. 7. Check cable entry path trench as ducts are to be properly sealed. 8. Visual Inspection, 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.




3.27 Control Cable

(Standard Reference is relevant SEC Transmission Specifications 11-TMSS-10, TES-P-119.29)



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. Check the path/separation of control & power cables 9. Visual inspection, size and rating confirmation. 10. Size checking against rating required.



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

Mega-ohms




3.28 Pilot Cables

(Standard Reference is relevant SEC Transmission Specifications 48-TMSS-01)



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




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 Mega-ohms

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 Mega-ohms

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 Mega-ohms

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.




(Table2.1)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


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


2Uo = 265 kV AC 60

380 kV XLPE/LPOF POWER CABLE

260kV 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




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 Mega-ohms

1



If IR < 1000 Mega-ohms, 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




3.29 Overhead Lines

(Standard Reference is relevant SEC Transmission Specifications 10-TMSS-06, TCS-P-122)

3.29.1 Mechanical check and Visual inspection


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 to run-off away 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 poles’ type and size 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 are being 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 bolts’ 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, torn. The rod should not be exposed at any of its location.

17.

Check that all line hardware (insulator, corona rings, vibration dampers, spacers, conductor clamps, warning spheres, warning lights, armor rods, counter weights, flag socket/keys etc..) are installed correctly and in correct locations as per 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. Make sure of correct clearance between jumper and structure as well as with other phases.

21. Check that overhead shield wire / OBGW 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 are meeting company standards.

24. Check circuit / phase identification plates, structure number, 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 with cable (if applicable).

28.

For terminal compound, check the following, if available, as per contract: a. Outdoor equipment such as surge arresters, CVT’s, 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.

30.

Regarding to the spacer dampers and vibrations on the 380kV Overhead Transmission Lines the following should be observed:-

a. Installed as per Manufacturer Instruction b. Spacer Damper Locations are as per the approved "In-Span Position

Table". c. Alignment of Spacer Dampers are perpendicular to Installed Using

Manufacturer d. Recommended Tools.

See check list item 3.29.3



1. Perform phase sequence / rotation check.

2. Perform sequence impedance and susceptances tests and mutual impedances (both zero and positive sequence for double circuits lines

3. Check tower foot earth resistance as per company standards. 4. Check the aircraft warning lights are properly functioning (if applicable). 5. Perform continuity and conductivity test

6. Perform Phase conductor insulation resistance test. 5kV for 1

minute




3.29.3 Check list

CHECK LIST FOR SPACER DAMPER INSTALLATION

Transmission Line Voltage Level Location (Area) Contractor Name Contract No Spacer Damper Manufacturer

Span No.

Installed as per Manufacturer Instruction

Spacer Damper Locations are as per the

approved "In-Span Position Table"

Alignment of Spacer Dampers are

perpendicular to

Installed Using Manufacturer Recommended Tools.

Remark

Verified

Not Verified

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Inspected by Contractor Supervisor: Verified By SEC Rep.: Date:




3.30 Protection and Control Panels.

(Standard Reference is SEC Transmission Standard 31-TMSS-01 and relevant Manufacturer’s Recommendations)

3.30.1 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.

3.30.2 Internal Panel Wiring Tests


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




ITEM DESCRIPTION REMARKS 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 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 sources 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.




ITEM DESCRIPTION REMARKS 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 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.

3.30.3 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.




3.30.4 Panel Device Tests


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.

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% 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.

General Mechanical Checks & Visual Inspection of Relays.

a. Inspect for defects and physical damage from shipping and handling. b. Any clamps or rubber bands used to secure moving parts to prevent

damage during transit should be removed after installation and before commissioning.

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





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

e. Check case cover and gasket for proper seal against dust. f. Check all installed equipment nameplate information for compliance

to approved drawings and equipment /material lists. g. Check that the relay serial number on the module, case and cover are

identical. h. 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.

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

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

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

l. 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. Check Ferrules.

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

n. Case earthing checked o. Auxiliary power supply rating checked and wiring checked for proper

polarity. p. Verify connections as per approved drawings. q. Use of ring type terminals for wire termination for current circuit

wires.

General Electrical Tests of relays. a. Check that rating of the relay agree with the Auxiliary Supply to

which it is connected. b. Check that DC Supplies are wired with the correct Polarity. c. Check that the frequency of the relay supply is compatible with the

system’s rated frequency. d. Verify that the secondary current for current operated relays matches

the used CT secondary current e. Verify proper phase shorting for CT field test switches and test plugs

used with current operated relays. f. Check that the relay nominal input voltage matches the VT voltage. g. Verify proper case shorting facility for current operated draw out type

relays. h. Make sure that all trip circuits are using high burden trip contacts

from the protection relays. i. Make sure that the low burden annunciation contacts are used only in

low burden circuits such as annunciation and indication.





j. Verify that the number of contacts and the contact

configuration (NC, NO ,CO) is the same in the drawing as it is in the relay

a. Voltage operated relays to have a pickup voltage less than 80% of the rated substation voltage to allow for proper operation of the relay even during substation DC under-voltage condition.

b. Check Annunciation LEDs and flags. c. Check Annunciation contacts d. Check Binary inputs. e. Check binary outputs and output contacts f. 500 V insulation tests shall be conducted between:

i. All electrically isolated circuits. ii. All circuits and earth.

g. Ensure that the error percentage between set values and actual values within the acceptable limit for all tested settings and check all error limits are included in test formats.

h. Check Watchdog or Internal Relay Fail contacts

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, 270 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 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.

3.30.5 Functional Checks

ITEM DESCRIPTION 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.

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 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.

If applicable.

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.

If applicable.

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 over current etc.) prevent operation of the ABTS.

c. Prove scheme for opening of bus 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.

3.30.6 Energization

ITEM DESCRIPTION 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 alarm relay settings are finalized and the relays are locked. g. Relays that have a backup battery for memory storage have their

batteries installed and the temporary battery covers removed. h. All switchgear and other power equipment testing are completed. i. All protection equipment is properly labeled. j. All fire/smoke alarm systems are fully tested and in service. k. All necessary fire fighting equipment is on site and accessible

without obstruction. l. 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




ITEM DESCRIPTION REMARKS 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 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.




3.31 Station Batteries

(Standard Reference is IEC 60623, clause 4 and relevant SEC Transmission Specifications 46-TMSS, TES-P-103)



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 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-

Room temperature shall be between 25 and 30 °C.




ITEM DESCRIPTION REMARKS 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.

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




3.32 Battery Charger

(Standard Reference Is IEC 60623, Clause 4, and Relevant SEC Transmission Specifications 46-TMSS, TES-P-103)



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

5. Check that all Alarm relays shall be auto-reset.

3.32.2 Electrical Test ITEM DESCRIPTION REMARKS

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




3.33 AC Distribution Panels

(Standard Reference is relevant SEC Transmission Specifications 31-TMSS-02, TES-P-

119.30)


ITEM DESCRIPTION REMARKS 1. Inspect for physical damage or defects including of quality of paint work 2. Verify circuits layout for conformance with breaker directory drawing

3. Inspect and verify ACDB Rating Plate, check bus-bar rating, short circuit withstand current & main MCCBs rating at 55oC.

4. Verify correct rating of each circuit breaker per design drawings 5. Check tightness of all bolted connections

6. 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

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


ITEM DESCRIPTION REMARKS 1. Insulation test of all buses and wirings 2. Phasing check 3. Functional check of main power contactor (or breaker) 4. Functional check of each branch breaker

5. Calibrate voltmeters, ammeters and watt-meters

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.

11. Apply trip test for all MCCBs by pole- pole current injection method




3.34 DC Distribution Panels

(Standard Reference is relevant SEC Transmission Specifications 31-TMSS-02, TES-P-119.30)



1. Inspect for physical damage or defects including of quality of paint work 2. Verify circuits layout for conformance with breaker directory drawing

3. Inspect and verify DCDB Rating Plate, check bus-bar rating, short circuit withstand current & main MCCBs rating at 55oC.





ITEM DESCRIPTION REMARKS 1. Insulation test for all busses and wirings 2. Polarity check 3. Functional check of main breaker 4. Functional check of each branch breaker 5. Calibrate voltmeters, ammeters and watt-meters 6. Functional check of meters and phase selector switches


8. Functional check of under voltage protection/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




3.35 LV AC Auto-Transfer Scheme/Switch

(Standard Reference is relevant SEC Transmission Specifications-31TMSS02, TES-P-119.30)



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. 4. Check tightness of all bolted connections (torque wrench method). 5. Check that all grounding is correct and securely connected (including

neutral bus).

6. Check mechanical/electrical interlocks.


ITEM DESCRIPTION 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.




3.36 Ground System

(Standard Reference is IEC 62271-100 and relevant SEC Transmission specifications 52-TMSS, TES-P-119.10)



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 to conform with standard requirements

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



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

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

4. Step and touch voltage measurement




3.37 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. Check that air compressors are fitted with: a. Automatic drain valve. b. Manual drain valve. c. Pressure relief valve. d. Oil level sight glass.

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.

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.




3.38 HVAC System

(Standard Reference is manufacturer’s recommendations and relevant SEC Transmission Specifications 73-TMSS, TES-100-01, TCS-K-100-01)



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 and 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. 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. b. Oil level sight glass. 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. 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.



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. Wire splices shall be avoided as much as possible

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:

a. Preliminary test. b. Pressure test. c. Leak test. d. Control test. e. Operation 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.




3.39 Dry Type Transformer

(Standard reference is relevant SEC Transmission Specifications)



1. Check nameplate for correctness 2. Check tightness of all bolted connections(torque wrench method

Check that all grounding is securely connected ,including star point neutral

3.

4. Perform all specific checks per manufacturer instructions 5. Check proper operation of all auxiliary devices (if applicable)



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 circuits functional tests



3.40 Ring Main Unit (RMU)

(Standard reference is relevant SEC Transmission Specifications 32-TMSS07)

3.40.1 Mechanical Check and Visual Inspection ITEM DESCRIPTION REMARKS

1. Check nameplate information for correctness 2. Check for damage to the body or the fuses 3. Check the interlock system 4. Check the level of insulation medium (SF6, Oil…etc)

3.40.2 Electrical Test ITEM DESCRIPTION REMARKS

1. Phasing

2. Insulation Resistance 5kV for 1 minute

3. Contact resistance using low resistance copper bar in place of fuses.

HV Test at 3

2geRatedVolta 4.

5. Earth Fault indicator test and function tests (trip / alarm contacts)



3.41 Capacitors Bank Test

(Standard reference is relevant SEC Transmission Specifications 43-TMSS-01)

3.41.1 General Mechanical checks and visual inspection ITEM DESCRIPTION REMARKS

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

2. Check nameplate information for correctness. 3. Check for overall body deformation.

4. Check tightness of the bolts according to specifications

5. Check leakage for any Cell of capacitors 6. Check that all grounding cables are securely connected

7. Check for any damaged paint for capacitors. 8. Check surge arrestor connections. 9. Check capacitor bushing tightness and bird proof capes. 10. Check for bushing cracks. 11. Check for proper termination. 12. Check for CT locations physically, 13. Check for VT locations physically.

3.41.2 Electrical tests


1. Check of test and measuring instruments calibration certificates. 2. Check of condition of battery cells of the T&M instruments. 3. Measure each individual capacitance. 4. Capacitance bank insulation test. 5. Capacitance bank measurement test. 6. Capacitance and dissipation factor measurement test. 7. Check individual insulation resistances. 8. Perform all specific tests per manufacturer's instructions. 9. Megger test phase to phase. 10. Capacitance bank neutral unbalance measurement.



3.42 Capacitor And Associated Reactor (Reactor Test)


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

2. Check nameplate information for correctness. 3. Check for overall body deformation. 4. Check tightness of the bolts according to specifications.

5. Check of foreign particles between the layers of the reactor coils. 6. Check that all grounding cables are securely connected.

7. Check the quality of the paint for reactors. 8. Check of any insulation cracks. 9. Check for proper termination.



1. Check of test and measuring instruments calibration certificates.

2. Check of condition battery cells of the Test and Measurement instruments.

3. Check main condition current path connection contact resistance. 4. Measure the insulation resistances of each phase to ground. 5. Measure the inductance of the harmonic filter inductors. 6. Temperature measurement at different joints after energization




3.43 Fire Detection and Protection Systems

(Standard reference is relevant SEC Transmission Specifications 90-TMSS, TES-B-106) 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.




3.44 Civil Work

(Standard reference is relevant SEC Transmission Specifications TCS-Q-113)

Witnessing of civil work is the responsibility of the CTA or DTA Project Department – Support Facility Projects Division to witness the work of the civil contractor. Transmission witnessing personnel shall check the accesses and ventilation that affects the main equipment. Civil Visual inspection:

a. The witness/ inspection engineer shall have the approved building construction schedule for the inspections that are required to be undertaken and approved for the project.

b. The witness / inspection engineer for civil works shall ensure that all checklist/progress reports for different stages of construction are readily available during his daily inspection of substation building or transmission lines including the list of civil work snags to know exactly the status of items that need to be completed before going up to the next stage of construction.

c. Consider the following civil items:

a. Check wall plastering and floor finishes for cracks b. Check fixing of false ceilings and floors c. Check basement/underground walls for possible water seepage (if water table is

present) d. Check basement/underground wall cable openings /ducts for possible seepage or

proper sealing e. Check Comfort Room drain slope f. Check Site drainage system for proper slope going to hand hole and/catch basins g. Check trenches for correct depth and width h. Check Tunnels and Trenches bottom for any loose dirt, rubble or water i. Check the trench, manhole and hand hole covers supports j. Check fixing of false ceilings and floors k. Check wall coatings l. Check fixings of all accesses including grounding (doors & hinges, Fence & Gates

and ladders) m. Check entry / exit stairways anti-slip, railing and safety barriers installation. n. Check Transformer firewalls and safety clearances o. Check all pavement (asphalted or concrete roads) p. Check cable trays and ladders installation and grounding.




3.45 Static VAR Compensation System

(Standard Reference is relevant SEC Transmission Specifications)

3.45.1 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.

3.45.2 SVC Transformer Tests

See Oil Filled Power Transformers, Section 3.1.

3.45.3 Harmonic Filters: Capacitors and Associated Inductors (Standard Reference is IEEE 1303-1994, IEEE Guide for Static VAR Compensator Field Tests and relevant SEC Transmission Specifications)

a. Mechanical Checks and Visual Inspection


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.

b. Electrical Tests


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. 5. Capacitance bank insulation test.




ITEM DESCRIPTION REMARKS 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.

3.45.4 Thyristor Controlled Reactor

(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 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.

b. Electrical Tests


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.

3.45.5 Cooling System Component Tests

(Standard Reference is IEEE 1303-1994, IEEE Guide for Static VAR Compensator Field Tests and relevant SEC Transmission Specifications)


ITEM DESCRIPTION REMARKS 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.




ITEM Description REMARKS4. Check pressure holding test on the expansion vessel/reservoir. 5. Check the pressure release valve and its operation on the 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.




ITEM DESCRIPTION REMARKS 35. Check the auto operation of ion exchanger/bypass valves with the

conductivity meter (if applicable).

b. Electrical Tests

ITEM DESCRIPTION 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.




ITEM DESCRIPTION REMARKS 24. Display messages check for alarms and trips. 25. Check PLC internal battery if present and note the date of 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.

3.45.6 SVC System Computer

Standard Reference is IEEE 1303, IEEE Guide for Static VAR Compensator Field Tests and relevant SEC Transmission Specifications)


ITEM DESCRIPTION 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.

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.




b. Electrical Tests


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. 39. Controller cards battery replacement date check. 40. Check of Remote communication with modem to SER. 41. Final trip tests.




ITEM DESCRIPTION REMARKS 42. Annunciator AC and DC supply MCB operation check. 43. Watch dog of SER check. 44. Operational check of thyristor bypass switch.

3.45.7 Protective Relay Tests and Check of Protection Schemes

(Standard Reference is manufacturer’s relay documents)



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

b. Electrical Tests


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.

3.45.8 SVC Energization: Sequence Of Events And On–Load Tests

a. 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.




ITEM DESCRIPTION REMARKS 6. Check that the operating division has issued a warning to the 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 no 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.




ITEM DESCRIPTION REMARKS 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.

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

3.45.9 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.

3.45.10 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




The following is an example of a Test Record Form submitted by the contractor for the Substation 9000 SVC pre-energization checks: 1. General

The following units are covered by this energization tests. TCR No. ____________________________________________ Filter No. _____________________________________________

2. Pre-Energization Checklist

Checks and Final Trip Test performed according to RQTR-710-D ------------------- 3. Energization of Substation Bus Bar

With bus bar energized voltage response to VAR Control was checked. Primary voltage according to existing metering: ________ kV Input to Data Acquisition Computer measured: Phase: R-Y: ________V Y-B: ________V B-R: ________V Value on software variable VRESP: _______________ Final parameter setting: VRESPNOM: _______________ (Voltage Response) Voltage selection checked: ---------------------------------------------------------------- All energized VT circuits measured: ------------------------------------------------------

4. Energization of Main Transformer

Recording of inrush current to transformer, see appendix: __________ Voltage input to Synchronizing Board YPQ 107 measured: Phase on ∆ - side: R-Y: ________V Y-B: ________V B-R: ________V Phase on Y – side: R-Y: ________V Y-B: ________V B-R: ________V Phase relation & sequence checked: ------------------------------------------------------- Synchronizing signals out from the synchronizing board checked: For each phase it was checked that the signals were as below: ----------------------- Visual check of transformer and bus bars done: ------------------------------------------- All VT circuits of protection and metering checked: --------------------------------------

5. Energization of Filters

Test result in 2000 852-192-D: No. of Units: _________ Performed: ----------- 6. Energization of TCR

Test Results in RQTR 703-D: No. of Units: _________ Performed: ------------ 7. Total Rating Test

Measurements of current and voltages taken from: __________________________________




------------------------------------------------------------------------------------------------------------ VT ratio: _____________________ CT ration: _____________________ Measurements at SVC maximum inductive:

Voltage Current

Phase R-Y Y-B B-R R Y B

Sec

Prim

Average measured values: Um = ___________ kV Im = ___________ A Measurement at SVC maximum capacitive:

Voltage Current

Phase R-Y Y-B B-R R Y B

Sec

Prim

Average measured values: Um = ___________ kV Im = ___________ A Unit Reactive Power capacity is calculated according to the formula. Q = √3 * Um * Im * (Un / Um)2 this gives ____________ Max inductive is: ___________ MVAR Max capacitive is: ___________ MVAR

8. Heat Run Test

Test with Max load on transformer, SVC operated at __________ MVAR. Ambient temp: __________

Time

Test with Max load on cooling system, SVC operated at __________ MVAR.




Ambient temp: __________ Valve temp: ____________

Time

9. Check of TCR Controls

Increase and decrease ramp of control signals for all phases checked: ------------------- TCR No.: _____________ See appendix: _____________

___________ ______________

Measurement of load-sharing:

TCR ________________ TCR ________________

Load Ph. R Ph. Y Ph. B Ph. R Ph. Y Ph. B

10. Check and Setting of Current Limit

Current limit for each TCR checked ------------------------------------------------------------- TCR No.: _____________ See appendix: ________________

_____________ ________________ Final parameter setting: ILIMLEV: ____________ Current limit

ILIMGAIN: ____________ Parameters corresponds to _______ A primary TCR current and _________ sec time constant

for the current limit operation.

11. Reactive Symmetry




Prim. Values Bus Voltage (kV) Delta Current (A) Impedance (Ω)

Q-tot Ph. a-b b-c c-a a-b b-c c-a a-b b-c c-a

Prim. Values Bus Voltage (kV) Delta Current (A) Impedance (Ω)

Q-tot Ph. a-b b-c c-a a-b b-c c-a a-b b-c c-a

12. Static Characteristic

Rated values on SVC used for calculation, are: Un: ________kV In: ________A Bn: ________mS

Measurement of susceptance and setting calculation in switching points:

Parameter Switch-

Point U (kV) I (A) B (mS) B (p. u.)

Name Value

Parameter Switch-Point

U (kV) I (A) B (ms) B (p. u.) Name Name

Measurement of B-prim versus BREF, after parameter setting:

BREF U (kV) I (A) B (ms) B (p.u.)

Graph of B-prim (p.u.) versus BREF, see appendix: _____________

Adjusted parameters to improve linearity: Name Value

____________ _____________ ____________ _____________




Final measurement of B-prim versus BREF:

BREF U (kV) I (A) B (ms) B (p.u.)

Graph of B-prim (p.u.) versus BREF After final adjustment: see appendix: __________ Final parameter setting: Name Value Name Value

_______ _______ ________ ________ _______ _______ ________ ________ _______ _______ ________ ________

Switching Control MAN-AUTO-MAN

Switching from MAN to AUTO and from AUTO to MAN works correctly See appendix: ______________ Final parameter setting: TFOL: ______________

(Follow function)

13. Operating Characteristic and Slope Setting

Final parameter setting: BREFNOM: ____________ (op. Char. and slope) SLOPE: ____________

Measurement of slope:

Uref Uprim - Uref Slope (%)

Uprim (kV)

Iprim (A) (value) (kV) (kV)




Uref Uprim - Uref Slope (%)

Uprim (kV)

Iprim (A) (value) (kV) (value)

Graph of slope at ___________%, see appendix: ________

Graph of slope at ___________%, see appendix: ________

Calculation of actual slope gives… set __________% Measured ____________% set __________% Measured ____________%

Step Response Test for Gain Optimization

Network short circuit power Sk at point of common coupling as follows:

During test: _______ MVA System minimum: ________ MVA

Steps in VREF was done to give responses of approx. __________ MVAR

Readings, see appendix: ________

Final parameter setting: VREGKI: _________

(SVC gain) VREGNI: _________

1. Control Logics etc.

Start: Complete sequences checked: see appendix: _________

Stop: Complete sequences checked: see appendix: _________


PAGE NO. 149 OF 241 TCSP105R01/TMA



Trip: Complete sequences checked: see appendix: _________ Ramp speed: Check and final settings

Final parameter setting: Name Value Corresponds to

(ramp speeds) _________ __________ ______________ _________ __________ ______________ _________ __________ ______________

Minloss function: Operation checked in all hysteresis area:

Final parameter setting: MLOSSLEV: ___________ (minloss function) MLOSST: ____________ Corresponds to ___________ seconds delay

Final parameter setting: Name Value Corresponds to __________ __________ ______________ __________ __________ ______________ __________ __________ ______________

Remote Control Functions: All applicable functions checked:

Final parameter setting: Name Value Corresponds to (remote control)

__________ __________ _______________ __________ __________ _______________ __________ __________ _______________

14. Redundancy Systems

It was checked that the SVC operates correct during the following change-overs to redundant functions.

Checked

To standby pump in cooling system: -----------------

To standby incoming AC supply: ------------------- ___________________________: ------------------- ________________________: --------------------- ___________________________: ------------------

Date of Approval: July 09, 2011


4. PROCEDURE FOR TESTING PROTECTION RELAYS

150 4.0 PROCEDURE FOR TESTING PROTECTION RELAYS151 4.1 General Mechanical Checks & Visual Inspection152 4.2


General Electrical Tests 153 4.3 Guidelines for Testing Digital& numerical Protection & control Relays and

IED’s 155 4.4 Auxiliary Relays 157 4.5 Timers (62) 158 4.6 Over/Under-Voltage Supervision Relays (59/27)159 4.7 Compensation Voltage Protection -59ND 160 4.8 Trip Circuit Supervision 163 4.9 Definite Time Over-Current & earth fault protection relay164 4.10 Inverse Definite Minimum Time (IDMT) Over-Current & earth fault protection

relay 165 4.11 Circuit Breaker Fail (CBF) Protection (50/62)166 4.12 Bus Bar Differential Protection RELAY (87B)171 4.13 Metrosil and Non Linear Resistor172 4.14 Synchronism Check (25) 173 4.15 Distance / Impedance Protection relay (21)175 4.16 Directional Over-Current and Directional Earth Fault Protection relay (67/67N)176 4.17 Directional Negative Phase Sequence over current- 67Q177 4.18 Line & Cable Differential Protection (87L/87C)179 4.19 Auto Re-closer function 180 4.20 Transformer Differential Protection relay (87T)181 4.21 Restricted Earth Fault (REF) Transformer Protection (64NP / 64NS) 182 4.22 Over/Under-Frequency & Frequency Rate of Change Protection (81/81R) 183 4.23 Automatic Voltage Regulation & Control (90)184 4.24 Disturbance & Fault Recorders (DFR)186 4.25 Sequence of Events Recorder (SOE)187 4.26 Annunciator (alarm module)188 4.27 Transducers 190 4.28 ACSE / ABTS / TOP 191 4.29 ACCS – Automatic Capacitor Control System



TCSP105R01/TMA

Date of Approval: July 09, 2011 PAGE NO. 151 OF 241

4.1 General Mechanical Checks & Visual Inspection



2. Any clamps or rubber bands used to secure moving parts to prevent damage during transit should be removed after installation and before commissioning.

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


5. Check case cover and gasket for proper seal against dust.

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

7. Check that the relay serial number on the module, case and cover are identical.

8.

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.




12.

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. Check Ferrules.


14. Case earthing checked

15. Auxiliary power supply rating checked and wiring checked for proper polarity.

16. Verify connections as per approved drawings. 17. Use of ring type terminals for wire termination for current circuit wires.



TCSP105R01/TMA


4.2 General Electrical Tests


1. Check that rating of the relay agree with the Auxiliary Supply to which it is connected.

2. Check that DC Supplies are wired with the correct Polarity.

3. Check the relay power consumption during operation at nominal rated voltage.

4. Check that the frequency of the relay supply is compatible with the system’s rated frequency.

5. Verify that the secondary current for current operated relays matches the used CT secondary current

6. Verify proper phase shorting for CT field test switches and test plugs used with current operated relays.

7. Check that the relay nominal input voltage matches the VT voltage.

8. Verify proper case shorting facility for current operated draw out type relays.

9. Make sure that all trip circuits are using high burden trip contacts from the protection relays.

10. Make sure that the low burden annunciation contacts are used only in low burden circuits such as annunciation and indication.

11. Verify that the number of contacts and the contact configuration (NC, NO ,CO) is the same in the drawing as it is in the relay

12. Voltage operated relays to have a pickup voltage less than 80% of the rated substation voltage to allow for proper operation of the relay even during substation DC under-voltage condition.

13. Check Annunciation LEDs and flags. 14. Check Annunciation contacts 15. Check Binary inputs. 16. Check binary outputs and output contacts

17. 500 V insulation tests shall be conducted between: a) All electrically isolated circuits. b) All circuits and earth.

18. Ensure that the error percentage between set values and actual values within the acceptable limit For all tested settings and check all error limits are included in test formats.

19. Check Watchdog or Internal Relay Fail contacts



TCSP105R01/TMA


4.3 Guidelines for Testing Digital& numerical Protection & control Relays and IED’s


1. Digital Protection relays with multiple possible configurations or multiple enable-able protection elements are to be tested as per their protection use in the scheme.

2. Devices that have multiple standards of characteristics to be tested as per SEC used standards (example IEC standard curves for Over-Current Time Inverse characteristics)

3. Proper configuration of local (and remote) CT / VT ratios especially for distributed differential arrangements

4.

Proper configuration of CT type (Protection, Metering) and accuracy class for IED’s to assure the correct current representation for sampled values (Sample Resolution: bits per sample & Sample Frequency: samples per second)

Ref IEC 61850-5 , Clause 13.7.4

5. CT Saturation or CT open secondary supervision in each bay unit of distributed differential arrangements with proper latching alarms and trip blocking logic

6. Communication channel test (one way total communication delay time, bit error rate)

<10ms delay time for sampled values <1ms delay time for trip commands Ref IEC 61850-5 , Table B.5

7. Continuous supervision of communication channel with associated panel alarm and remote alarm and trip blocking

8. Any Internal Relay Fail (IRF) or Software supervision watchdog contacts or DC supply failure contacts available on the relay to be incorporated in the substation alarm scheme.

9.

When a relay is placed in loop-back mode or a self test state and is not responsive for to live CT / VT inputs, it should have a local indication in the relay / control panel as well as a latching remote alarm indicating that the protection is out of service.

10. GPS Time lock and synchronization test at time master

11. Verify Substation master clock distribution to slave devices , Check that report/logging timestamp accuracy matches the documented timestamp quality of the server

Ref IEC 61850-10, Clause 6.2.4.16.1

12. Verify that the event ‘time synchronization communication lost’ is detected after a specified period

Ref IEC 61850-10, Clause 6.2.4.16.2

13. IP addressing assigned as per SEC standards and clear IP address labels on the front of every Relay / IED

14. Verify use of non-volatile memory or internal battery for continuous storage of protection settings and relay configurations even with total DC failure.



Configuration should be signed from manufacturer.

Verify that the final configuration of the relay is fixed and not accessible without proper software or authorization.

15.

16. Check Relay configuration and interface with PC. Ensure that relay Disturbance Fault recorder & internal event recorder are

working properly. 17.

The reference values (% tolerance allowed) for each device should be compulsory mentioned on test report

18.

Ensure that the error percentage between set values and actual values within the acceptable limit For all tested settings and check all error limits are included in test formats.

19.

Any testing performed to digital or electronic equipment requires the use of proper antistatic gear (anti-static mat, anti static wrist guard) for anyone in contact with the equipment.

20.

Testing of numerical control:

Mimic and single line diagram on the relay display has to be checked according to approved single line diagram of SS Control configuration and all functions the relay has to be checked according to approved schematic diagram and approved configuration. Interlocking logics have to checked and studied according to approved scheme and conditions. Check of all breaker, disconnector and earth switch positions. The position indications are checked by local operation in the field and the physical position of every device has to be compared with the shown position on the local mimic, the displays of the relays and on the SAS. Check of all breaker, disconnector and earth switch commands. The command has to be checked for the possible modes (Local, Emergency & Remote,). Local operation mode at the relay display can be selected by selector button on the relay display. Every switching devices has to be operated (open and close) in the local mode. Remote mode at SAS at the relay display can be selected by selector button on the relay display. Every switching devices has to be operated (open and close) in the remote mode.

21.

The proper LED indication has to be checked. The interlocking logic for local and remote operation can be either checked from locally from relay display or remotely from SAS. These conditions have to be checked according to the approved base design document. Eventually the system contains an interlocking override function which has to be checked by the certain instance (e.g. Mimic, UBC or SAS.) Checking of close blocking by lock out relay. checking of synchrocheck function check of measurement Check of automatic voltage regulator. Check of alarm panel.

Remark: SUBSTATION AUTOMATION SYSTEM procedures must be submitted from suppliers at least 6 months before starting commissioning for study by SEC.

TCSP105R01/TMA



4.4 Auxiliary Relay

(Auto Reset Auxiliary Relays (Auto Reset, Hand Reset, Electrically Reset, Bi-Stable, Trip Lockout Relay (86) & Trip Auto Reset Relay (94))

4.4.1 General Mechanical checks and visual inspection.


1. General Visual Inspection As per 4.1 On Units fitted with hand reset flag indicators, check that the flag is free to fall before, or just, any contacts closes. Make sure that the reset mechanism in the cover is correctly located with respect to the relay element and the flag (or mechanism) can be reset.

2.

3. Check condition of any connectors, contacts alignment and travel. 4. Check armature gap. 5. Check Lockout mechanism. For hand reset

auxiliary relays, Trip Lockout Relay (86) and Bi-stable relay

Check Reset mechanism.

6. For electrical reset auxiliary relays



1. General Electrical Tests As per 4.2 2. Check the continuity of the contacts. 3. Check the resistance of all output contacts.

Check the pick up voltage and current of operating Coil. The relay should switch cleanly with one movement.

4.

Check the AUTO-RESET function For auto reset auxiliary relays, Trip Auto Reset Relay (94)

5.

6. Check the Reset mechanism For hand reset, Check pick up voltage and current of Reset Coil. For electrically

reset & Bi-stable relay

7.

Check Drop off voltage and current of Reset Coil. For electrically reset & Bi-stable relay

8.

Check the operating time of the Reset Coil at lowest nominal supply voltage

For electrically reset 9.



TCSP105R01/TMA



10. Check the operating time of the operate Coil at lowest nominal supply voltage.

For electrically reset

11.

Check Operate Coil and Rest Coil power consumption during operation at nominal rated voltage.

For auto reset, hand reset, Bi-stable, electrically reset, Trip Lockout Relay (86), Trip Auto Reset Relay (94)

12. Check operate and Reset Coil resistance. For electrically reset

13. Check external Reset input if applicable. For electrically reset

14. Check Change-Over time for contacts which makes/breaks. For Bi-stable relay

15. Check power consumption of operate and Reset Coil. For Bi-stable relay

16.

Verify trip test for circuit breaker and closing block. Trip Lockout Relay (86), Trip Auto Reset Relay (94)

17. Check Drop off voltage and current of operating Coil. 18. Check the operating and Reset time at lower nominal supply voltage. 19. Check Relay Burden during operation at nominal rated voltage. 20. Check Operating coil resistance. 21. Check the reset ratio ( reset ratio = drop off / pick up) 22. Check power consumption of the relay. 23. Perform the functional test of the relay for which it is being used. 24. Check operation indicator /Flag/LED function.

For auto reset, hand reset, Bi-stable, electrically reset, Trip Lockout Relay (86), Trip Auto Reset Relay (94)



TCSP105R01/TMA


4.5 Timers (62)

4.5.1 Mechanical checks& visual inspection


1. General Visual Inspection As per 4.1

2.

On Units fitted with hand reset flag indicators, check that the flag is free to fall before, or just, any contacts closes. Make sure that the reset mechanism in the cover is correctly located with respect to the relay element and the flag (or mechanism) can be reset.

3. Check condition of any connectors, contacts alignment and travel. 4.5.2 Electrical tests


1. General Electrical Tests As per 4.2

2. Ensure correct values of external resistors (where applicable) and check these are wired to the correct relay terminals.

3. Check Pick-up and Drop-off Voltage. 4. Check current at Pick-up\ drop-off voltage. 5. Check the contact operating time pickup\ drop-off Test. 6. Check the burden at rated voltage.

7.

Check Timing at different points setting. Note that the measuring accuracy depends upon the accuracy of the instrument used.

8. Check that trip indicator operates correctly and can be reset using reset mechanism. For versions fitted with LEDs trip indicator check proper operation of LEDs.

9. Check that contact operate by doing continuity check.

10. Check that necessary trip and alarm circuits are energized according to relevant Schematic diagram by operating the relay with trip and alarm links restored.

11. Timer range to match drawing

4.5.3 Related Tests ITEM DESCRIPTION REMARKS 1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3



4.6 Over/Under-Voltage Supervision Relays (59/27)

4.6.1 General Mechanical checks, visual inspection and Electrical checks.


1. General Visual Inspection As per 4.1 Ensure the correct values of external resistors (where appropriate) are

wired to the correct relay terminals. 2.


3.

4. Check condition of any connectors, contacts alignment and travel. 5. Check Current Supervision feature in Under Voltage relay.


ITEM DESCRIPTION REMARKS As per 4.2 &

1. General Electrical Tests 4.3 if applicable 2. Check measurements and error ratio

3. Check over voltage pick-up and drop-off and reset ratio. 4. Check under voltage pick-up and drop-off and reset ratio 5. Check low voltage blocking 6. Time-voltage characteristic test. 7. Instantaneous unit test. 8. Check binary inputs and outputs and annunciations. 9. Check Nominal contact voltage AC/DC. 10. Check for visual indication for power supply, pickup and reset. 11. Check Current Supervision feature in Under Voltage relay. If applicable.

4.6.2 Related Tests ITEM DESCRIPTION REMARKS

1. Testing the Final Setting as per approved setting 2. Final Trip Test As per 5.11

TCSP105R01/TMA



4.7 Compensation Voltage Protection 59ND

4.7.1 General Mechanical checks and visual inspection


1 General Visual Inspection As per 4.1



As per 4.2 & 1. General Electrical Tests 4.3 if

applicable Check that rating of the relay agree with the auxiliary supply to which it is connected.

2.

Check the Rated Bus Voltage & Rated Neutral voltage and Rated Frequency are educated to SS facilities.

3.

Check relay applied configuration according to approved configuration and to schematic drawing.

4.

Perform relay self-test procedure and external communications checks on digital/numerical relays.

5.

Check all binary inputs and outputs contacts, Indication LEDs and alarm and trip indication messages on LCD and event & fault recorder.

6.

Check the VT MCB trip will block the protection element and check Led's for MCB /VT failure or fuse failure.

7.

8. Check test switch/plug for correct function. 9. For Numerical relays perform Secondary injection measurements for

neutral voltage and Bus voltage and compensation voltage and voltage difference.

Percentage error % ( error% = (measured – expected)/expected

10. Check The compensation voltage setting saving during DC off. 11. Check Over Voltage difference pick-up and drop-off for Neutral voltage

and Bus voltage (low set stage).

12. Check Over Voltage difference pick-up and drop-off for Neutral voltage and Bus voltage (high set stage).

13. Check Tripping Time of over voltage difference (low set stage).

14. Check Tripping Time of over voltage difference (high set stage). 15. Check the approved applied settings.

4.7.2 Related Tests


1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11



TCSP105R01/TMA


4.8 Trip Circuit Supervision

4.8.1 Trip Circuit Supply Supervision

a. General Mechanical checks, visual inspection and Electrical checks. ITEM DESCRIPTION REMARKS


2.


3. Check condition of any connectors, contacts alignment and travel. 4. Check armature gap. 5. Check for proper operation of LEDs.

b. Electrical tests



2.

Measure Trip Supply and Alarm Supply. Alarm and Trip Supply should be separate from each other.

3. Check Protective fuse rating.

4. Ensure correct values of external resistors (where applicable) and wired to the correct relay terminals.

5. Check the continuity of the contacts. 6. Check the resistance of all output contacts. 7. Check pickup Voltage / Drop –off voltage and measure current. 8. Check power consumption when the relay is energized. 9. Check Relay Coil Resistance. 10. Initiate Alarm by removing fuse. 11. Check Nominal contact voltage AC/DC. 12. Check for visual indication for power supply, pickup and reset.



TCSP105R01/TMA


4.8.2 Trip Circuit Supervision, without pre-closing supervision

a. General Mechanical checks, visual inspection



2.



b. Electrical tests




3. Check that DC Supplies are wired with the correct polarity.

4.




7. Check the continuity of the contacts. 8. Check the resistance of all output contacts.

9.

Check pickup / Drop –off for both voltage and current of the operating coil.

External resistors (where applicable) should be taken into account during application of voltages.

10. Check power consumption when the relay is energized. 11. Check operating Coil Resistance. 12. Check voltage across relay coil when circuit breaker is open and closed.

13. Check voltage across external resistors (where applicable) when circuit breaker is open and closed.

14. With the circuit breaker closed apply a temporary Short circuit across each of the external resistors (where applicable) of the trip circuit. Ensure the C.B. does not trip.

15. Initiate Alarm by removing fuse. 16. Check Nominal contact voltage AC/DC. 17. Check for visual indication for power supply, pickup and reset.



TCSP105R01/TMA


4.8.3 Trip Circuit Supervision, with pre-closing supervision

a. Mechanical checks, visual inspection



2.



b. Electrical tests




3. Check that DC Supplies are wired with the correct polarity.

4.





9.

With the C.B. Open Check pickup / Drop –off for both voltage and current of Operating coil-1.

External resistors (where applicable) should be into taken account during application of voltages.

10. With the C.B. closed Check pickup / Drop–off for both voltage and current of Operating coil-2.

11. Check power consumption when the relay is energized. 12. Check operating Coil Resistance. 13. Check voltage across relay coil when circuit breaker is open and closed.






TCSP105R01/TMA


4.9 Definite Time Over-Current & earth fault protection relay




2.


3. Check condition of any connectors, contacts alignment and travel. 4. Check armature gap.



1. General Electrical Tests As per 4.2 & 4.3

if applicable 2. Check for External resistors, where applicable. 3. Check relay configuration. 4. Check that protection relay settings have been entered correctly.

5. Perform relay self-test procedure and external communications checks on digital/numerical relays.

6.

Check Pick-up & Drop off Values of Over Current for all phases & Earth fault (Low set stage.) ( for several setting adjustments )

Reset Factor = DO / PU % (Approx. 95 % for I> / In ≥ 0.5 )

7. Check Tripping Time of Over Current for all phases & Earth fault (Low set stage.) ( for several setting adjustments )

8. Check Pick-up & Drop off Values of Over Current for all phases & Earth fault (High set stage). ( for several setting adjustments )

9. Check Tripping Time of Over Current for all phases & Earth fault (High set stage.) ( for several setting adjustments )

10. Witness binary inputs and outputs and annunciations.

11.

Check displayed measurements in primary or secondary values if applicable.


4.9.3 Related Tests





TCSP105R01/TMA


4.10 Inverse Definite Minimum Time (IDMT) Over-Current & earth fault protection

relay



4.10.2 Electrical tests ITEM DESCRIPTION REMARKS


if applicable

2.

Check displayed measurements in primary or secondary values if applicable.


3. Check for External resistors, where applicable.


5. Check Pick-up & Drop off Values of Over Current for all phases & Earth fault (Low set stage.) ( for several setting adjustments )


7. Check Normal inverse characteristics on different multiples of plug setting /current setting. (For all 3 phase over current & earth fault )

2x, 5x, 10x Is

8. Check Very inverse characteristics on different multiples of plug setting /current setting. (For all 3 phase over current & earth fault )

2x, 5x, 10x Is

9. Check Extremely inverse characteristics on different multiples of plug setting /current setting. (For all 3 phase over current & earth fault )

2x, 5x, 10x Is

10. Check Long time inverse characteristics on different multiples of plug setting /current setting. (For all 3 phase over current & earth fault )

2x, 5x, 10x Is

11. Check Tripping Time of Over Current & Earth fault (High set stage.)

12. Check the over current & earth fault indication LED's, display and fault & event recorders.

13. Check tripping indication.





TCSP105R01/TMA


4.11 Circuit Breaker Fail (CBF) Protection (50/62)



1. General Visual Inspection As per 4.1 2. Indications checked

4.11.2 Electrical test


1. General Electrical Tests As per 4.2 &

4.3 if applicable

2.

Measurements a. pick up (PU) b. drop out (DO) c. ratio DO/PU %

Check at every plug tap and multiplier

3. Check CBF for mechanical protection initiate low current mode in the relay if applicable

If applicable

4. Check relay operating time for all re-trip stages Current applied

2I setting

5. Check relay setting PLUG TAP x MULTIPLIER

At each phase

6. Check annunciation LEDs 7. Check annunciation contacts 8. Contact resistance of tripping and alarm checked

4.11.3 Related Tests


1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. End to End test As per 5.17 ,

5.18 (when remote tripping is applicable)



TCSP105R01/TMA


4.12 Bus Bar Differential Protection RELAY (87B)

4.12.1 High Impedance Bus Bar Differential Protection

a. General Mechanical checks and visual inspection

ITEM DESCRIPTION REMARKS 1. General Visual Inspection As per 4.1 2. Indications checked 3. CT Supervision indication and flags should be latching

4. CT ratios, CT Matching for all CT’s in the same zone or use of correct matching CT’s and CT grouping per protection zone.

b. Electrical test



4.3 if applicable

2. Check power supply status

3.

Check operating and drop out a. pick up b. drop out c. reset factor

Check at many operating setting values and final setting.

4. Check relay operating time ( at many setting values and final setting)

5.

Check tripping criteria (if applicable) OPTION 1: DIFFERENTIAL TRIPPING ENABLED TOGETHER WITH AN EXTERNAL STARTS. OPTION 2 : DIFFERENTIAL TRIPPING ENABLED TOGETHER WITH INSTANTANEOUS PICK UP OF BUS WIRE SUPERVISION OPTION 3 : DIFFERENTIAL TRIPPING ENABLED WITHOUT FURTHER CONDITIONS

6. Check bus wire supervision 7. Check disconnector replica. (Bus image) 8. Check stabilizing connection system with resistor & metrosil 9. Check all command relays 10. Check stability & sensitivity test by secondary injection 11. Verify that the total operating current in limits

12. Check the drawn secondary current in each element and verify that it's in limit for each element

By secondary injection

c. Related Tests


1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.7 3. Final Trip Test As per 5.11 4. On Load Test As per 5.23.6



TCSP105R01/TMA


4.12.2 Low Impedance Bus Bar Differential Protection




b. Electrical test


1. General Electrical Tests As per 4.2 & 4.3 if applicable

2.

Measurements a. Measuring at every Bay Unit (BU). b. Measuring Idif and Istab Check Zone (CZ) at Central Unit (CU). c. Take the reading of Idif and Istab of Bus Zone (BZ) and CZ Form

the testing equipment

By injecting current from test switch of bay unit. Bus zone (selective zone) (discrimination zone) depending on which isolator closed.

3.

Bus bar protection diff. current alarm test (at many setting values and final setting) Measure the pickup Measure the drop off Measure the time Check the relay LED

Idiff supervision : ON Take these measurement at every BZ and CZ

4. Bus bar protection diff. current

4.1

Pickup test (at many setting values and final setting) Measure the pickup current at CZ Measure the operate time at 2Isetting at CZ and check the relay LED. Measure the pickup current at BZ Measure the operate time at 2Isetting at every BZ and check the relay LED

Idiff supervision : OFF

5. Bus bar protection diff. current slope test

5.1

Bus zone. ( discrimination zone) Measure Idiff and Istab Calculate K = Idiff / Istab ( or according to relay manual)

Define the K factor (slope setting) Connect Bay unit – X and Bay unit – Y on the same Bus Zone (BZ). Inject I1∟0 at BU-X & I2∟180 BU-Y with equal magnitude,



TCSP105R01/TMA



decrease / increase any one up to trip ,measure : Id & Is ,then Calculate slope = Id / Is Note that : Idiff = | I1 - I2 | and IStab = | I1| + | I2 | and K= Id/Is

5.2

Check zone Measure Idiff and Istab Calculate K = Idiff / Istab ( or according to relay manual)

Verify this connection Bay unit – X and Bay unit – Y on the same BZ , but , Bay unit – Z on a different BZ . Inject I1∟0 ≥ 2.0 A(or according to setting) threshold (CZ), Increase I2∟180 up to trip, Calculate. slope = I2/I1 BU-X,Y and Z should be of same ratio

6.

Breaker failure protection test (if it is included in BBP relay) Measure pickup current (for all phases) Measure drop off current (for all phases) Measure time stage 1 Measure time stage 2 Check relay LED's Note that: CBF. Stg.-1 trip is related to the local feeder (bay unit).

CBF. Stg. - 2 trip is related to the bus zone of that feeder (bay unit).

Config. , B/I CBF start 3p , Led CBF trip , B/O-1 CBF rep. trip 3P ( stg.-1 ) B/O-2 CBF trip 3P ( stg.-2 ) Increase current up to P/U and decrease up to D/O For timing Stg – 1 use B/O-1 , For timing Stg – 2 use B/O-2

7. Breaker failure protection special test

7.1

CB faulty Config. ( B/I C.B. not ready ).if this B/I is activated in the same time with (B/I CBF start 3poles ) The relay will trip the entire bus bar at stage 1 time or as per the time setting for T-BF CB fault.



TCSP105R01/TMA



).if this B/I is activated in the same time with (B/I CBF start 3poles ) The relay will trip the entire bus bar at stage 1 time or as per the time setting for T-BF CB fault.

7.2

Low current mode If this function : ON ,C.B closed , CBF start 3poles ,without current The trip(CBF trip L123 ) will issued after time T-BF low current (without CB fault) If CB fault is there , the trip (CBF trip L123) will issued after time T-BF CB fault

7.3

End fault protection Config.( B/O to End Flt Trip) , make this function : ON and if the (C.B is open ) is activated with injected current, The End fault trip will issued immediately to trip the remote End .

7.4

Testing function Measure time of CB faulty (ms) Measure time of I < (ms) Measure time of End fault (ms) Check the relay LEDs

Measure at every bay unit

7.5 Diff. current super vision function checked



TCSP105R01/TMA



a) Check Blocking during fault. b) Check Blocking till release c) Check Alarm without blocking

7.6

Isolator supervision function checked a) Check Blocking during fault. b) Check Blocking till release c) Check Alarm without blocking d) Blocking till acknowledge

7.7 All LED's checked 7.8 All binary input checked 7.9 All command relay checked

7.10 All signal relay checked

7.11

All bay unit checked a ) check DC Fail ( for both setting old status and close ) b ) check Comm. Fail ( for all Bays ) c ) check Out Of Service according to scheme according to relay

features availability and its manual) d ) check Maintenance (for all Bays)

7.12 Fault recorder checked 7.13 BF inter-trip with BB fault

7.14 Check the commissioning of the used Auxiliary contacts of breakers and Isolators are in line with Manufacture recommendation

7.15 Check the close command is terminated for all bays which take breaker status in account

7.16 Check power supply


1. Final Setting as per approved setting2. Stability & Sensitivity Test by simulation of external and internal faults As per 5.133. Function Test & Scheme Check As per 5.74. Final Trip Test As per 5.115. On Load Test As per 5.23.6



TCSP105R01/TMA


4.13 Metrosil and Non Linear Resistor


ITEM DESCRIPTION REMARKS 1. General Visual Inspection As per 4.1

2. Visual inspection of protective cover / shroud with high voltage caution label



1.

Check the characteristics of the Metrosil Apply the appropriate voltage and measure the corresponding current and draw a curve between current and voltage. Compare the results with the approved characteristics


ITEM DESCRIPTION REMARKS 1. On Load TEST As per 5.23.6

(BB), 5.23.5 (REF) (measure metrosil current during on load stability)



TCSP105R01/TMA


4.14 Synchronism Check (25)



4.14.2 Electric Tests



2. Check Measurements & percentage error 3. Check Voltage elements pickup and drop off

3.1 Check bus live range 3.2 Check bus dead range 3.3 Check line live range 3.4 Check line dead range 3.5 Check bus under voltage detector 3.6 Check line under voltage detector 3.7 Check difference voltage detector

4. Check Phase angle difference (∆) 5. Check Frequency difference (∆f) 6. Check timers (slip time and synchronism time) 7. Check under voltage block feature 8. Check binary output contact and indication led 9. Check blocking for synchronizing in case of FUSE FAIL OCCUR 10. Check Watchdog Contacts 11. Check Live Line Dead Bus Synchronism bypass 12. Check Dead Line Live Bus Synchronism bypass

13. Check Dead Line Dead Bus Synchronism bypass. (should be not bypass or according approved setting )



1. Final Setting as per approved setting 2. Function Test & Scheme Check

As per 5.3 Be sure that the reference used voltages for all bays are synchronized. Be sure during VT loop test, control function test and LCC function test the synchronizing voltage circuit are correct and C.B close block conditions are correct.



TCSP105R01/TMA


4.15 Distance / Impedance Protection relay (21)


ITEM DESCRIPTION REMARKS 1. General Visual Inspection As per 4.1 2. CT shorting checked 3. Indications checked 4. Contact resistance of tripping and alarm checked



1 General Electrical Tests As per 4.2 & 4.3

if applicable

2 Measurement checking: Secondary & primary values of V, I, angle, P& Q for all phases.

Zero sequence setting should be zero

3 Relay configuration should be approved and signed by manufacturer & PED.

4 Distance protection pick up threshold Apply approved

final setting for testing

4.1 Check Phase fault current threshold detection (for all phases) 4.2 Check Earth fault current Thresholds 4.3 Check zero sequence voltage Threshold check 4.4 Check Dead line detection

5 Check all Zones reaches & Time Testing for all phases and all types of faults.

Apply approved final setting for testing

6 Distance directionality check 7 Distance Tele-protection scheme

7.1 Check POTT 7.1.1 Check Weak in-feed FUNCTION

7.1.1.1 Check Echo only 7.1.1.2 Check Echo and trip 7.1.1.3 Check under voltage pick up for local trip 7.1.1.4 Check Current Reversal Logic ( with POTT Scheme)

7.2 Check Permissive Under Reach ( PUTT ) (Z1 extension Acceleration) 7.3 Check Blocking Scheme

7.3.1 Check Current Reversal Logic ( with Blocking Scheme) 7.4 Check Unblocking Scheme 7.5 Direct transfer trip (DTT) 8 Check Power Swing function 9 Check Switch On to Fault SOTF

9.1 Check SOTF associated with distance protection 9.2 Check SOTF associated with back up over current 9.3 Check Instantaneous high speed SOTF O/C 10 Fuse failure monitoring

10.1 Check Fuse failure measurement For current less



TCSP105R01/TMA



than the setting of Maximum current threshold and zero voltage appear for more than the setting, FFM(Fuse failure monitoring) will appear after pre-set time (for example 10 seconds) with distance blocking.

10.2 Check maximum voltage threshold U< ( 3 phase ) 10.3 Check BI blocking (for VT failure) & indication.

11 Check Fault locator Apply approved


12 Check Internal Recorder Apply approved


13 Memory Voltage Test Apply approved


13.1 Check Memory time measurement test 13.2 Check Memory voltage measurement test

14 Back Up Over Current Protection & Stub protection if applicable: (Emergency)

Same test like over current relay

14.1 Definite time Pick up & drop off

Reset Factor = % DO/PU (> 95 % for I > / In ≥ 0.5 )

14.2 Low set stage I> 14.3 High set stage I>> 14.4 Normal inverse characteristics 14.5 Very inverse characteristics 14.6 Extremely inverse characteristics 14.7 Long time inverse characteristics



1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. End to End test As per 5.17 5. On Load Test As per 5.23.3



4.16 Directional Over-Current and Directional Earth Fault Protection relay (67/67N)


1. General Visual Inspection As per 4.1 2. CT shorting check


As per 4.2

TCSP105R01/TMA


1. General Electrical Tests & 4.3

if applicable 2. Measurement: Injected quantities ( V and I ) 3. Measurement: P,Q,F, Directionality 4. Check the directional operating characteristic angle 5. Check the polarizing voltage (3Uo) Pick up and Drop off

Check Earth fault over current group (non directional& directional element )

6.

7. Blocking of directional elements 8. Fuse fail 9. VT Fail 10. Communication Fail 11. Blocking Scheme with carrier received

Tele-Protection Schemes (Blocking, Unblocking, Directional Comparison, Direct Transfer Trip)

12.

Check Fuse failure measurement Blocking of directional element

13.

14. Check maximum voltage threshold U< ( 3 phase ) 15. Check BI blocking (for VT failure) & indication.

Check the VT MCB trip will block the directional element and the signal send

16.

17. Memory Voltage Test 18. Check Memory time measurement test 19. Check Memory voltage measurement test 20. Self Test the relay if applicable


ITEM DESCRIPTION REMARKS 1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. End to End test 5. On Load Test As per 5.23.3


4.17 Directional Negative Phase Sequence over current- 67Q






As per 4.2 & 1. General Electrical Tests 4.3 if

applicable Check relay applied configuration according to approved configuration and to schematic drawing.2.

Adjust relay time setting as instantaneous zero seconds. Adjust the tester direction angle as forward direction. Check Pick-up & Drop off Values of the Current and voltage, for all phases and select type of fault for testing.


3.

4. Check test results for operating pick up values according to simulated fault types as the following:-Single phase to earth fault: the injected current at which the protection will operate = 3 expected setting pick up current value. Phase to phase fault: the injected current at which the protection will operate = √3 (expected setting pick up current value). 3 phase fault the relay will not operate

5. Check the directional operating characteristic angle by injecting suitable value of voltage and 1.5 of operating pick up value of current

and start from angle =0 to 360. Check test results and characteristic for determination operating and blocking areas.

6. Check the VT MCB trip will block the directional element.Check blocking voltage for directionality. Check Led's for MCB /VT failure or fuse failure 7.

8. Check led's for faulted phase identification /phase selection



1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. On Load Test


4.18 Line & Cable Differential Protection (87L/87C)


ITEM DESCRIPTION REMARKS 1 General Visual Inspection As per 4.1



As per 4.2 & 1. General electrical tests 4.3 if

applicable 2. Check Measurements if applicable 3. Check Differential Protection 3.1 Check I –DIFF > pick up and drop off and its time 3.2 Check Under switch on condition if applicable 3.3 Check I –DIFF >> pick up and drop off and its time 3.4 BIAS CHARACTERISTIC TESTING (for digital relays) 3.5 Unrestrained Current Pick-up Test and its time 3.6 Check Inrush restrain current if applicable

2nd harmonic blocking test: Inject one phase current as an example (1A - 60 HZ and 0.22 A - 120 HZ) the relay will not trip because of second harmonic inrush block

3.6.1

Cross blocking test: Inject one phase current as an example ( 1A - 60 HZ and 0.22 A - 120 HZ) and another phase by (1A – 60 HZ) The relay will trip after the summation of time by cross blocking with 2nd harmonic

3.6.2

3.7 Check 5th harmonic test 4. Check Thermal over load protection 4.1 Check with memory

Check with memory without preload Before injection you must reset the temperature rise

a. Calculate the trip time for thermal relay 4.1.1 b. Calculate the thermal alarm time (stage 88%)

Check with memory with preload 4.1.2 a. Calculate the trip time for thermal relay

b. Calculate the thermal alarm time (stage 88%) 5. Check that the differential element blocking with communication failure

Capacitive charging current test procedure:


If applicable a. Activate the VTS and set value for line susceptance. b. Applied voltage at the local relay with out current and read from

the relays the differential current and base current. c. Repeat the above steps with change the values of the voltage and

susceptance.



TCSP105R01/TMA



Current transformer supervision test procedure: a. Simulate CTS state at local relay by inject –ve sequence current. b. Increase currents gradually till reach the setting. c. Check the block state of the relay and measure the block time. d. Check the restrain state of the relay. e. Check the alarms appear at the relay at local & remote ends. f. Check the value of the relay operates (Is1CTS). g. Simulate CTS, then decrease currents gradually till the relay reset

CTS state h. Check the value of relay operates.

Repeat the above steps for remote end

If applicable

6. Check Back Up Over Current Protection As per 4.12

7.

Check there is +ve can be send from test socket while test plug inserting to block the relay in order to prevent wrong operation.

For some relays which there were bad history of wrong operation



1. Final Setting as per approved setting 2. Stability & Sensitivity Test by simulation of external and internal

faults (if possible with high burden primary injection set for short power cables)

3. Function Test & Scheme Check As per 5.3 4. Final Trip Test As per 5.11 5. End to End test As per 5.17&

5.18 (by secondary injection, specially if Stability & Sensitivity test via primary injection is not possible)

6. On Load Test As per 5.23.2



TCSP105R01/TMA


4.19 Auto Re-closer Function






2.

Check the operation a. Simulate the digital Input as trip and CB closed. b. After the dead time, the re-closer signal will be generated by the

relay. c. Repeated tripping of the breaker will result in another closing shot

(depending on the setting for dead time and the setting for number of shots)

d. After the final closing of Circuit breaker, apply the trip and notice that the relay will be locked out without any issuance of re-closer command.

e. Repeat the test as stated above with different dead timings. f. Check the re-closer conditions and remove them one by one and

notice the status

3. Check dead times 4. Check reclaim time 5. Check close pulse duration 6. Check re-close signal 7. Check lockout function 8. Check frequent operation function 9. Check circuit breaker fail to close & alarm contact

10. Check Re-closer blocking depending on the readiness of the circuit breaker.



1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11

(check proper re-closing and lockout during trip test depending on trip source)

4. End to End test (check proper re-closing and lockout with local and remote trip depending on trip source)



TCSP105R01/TMA


4.20 Transformer Differential Protection relay (87T)

4.20.1 General Mechanical Checks And Visual Inspection



2. CT ratios, and matching CT selection is correct for TX type (Star or Delta) and for Vector Group




2. Through current restrain/stability test. For all phases and all types of faults

By Secondary Injection

3. Pick-up\drop off differential current Id> test (without zero sequence elimination and with it). For all phases and all types of faults and transformer sides.

4. Pick-up\drop off differential current Id>> test. For all phases and all types of faults and transformer sides.

5. BIAS CHARACTERISTIC TESTING for all phases and all types of faults

6. 2nd & 5th Harmonic restraint Test. For all phases and all types of faults 7. Cross blocking function test. For all phases and all types of faults 8. Negative sequence Relay Operating Angle test ( if it is applicable) 9. Sensitive negative sequence ( turn-to-turn fault ) test( if it is applicable)



1. Final Setting as per approved setting 2. Stability & Sensitivity Test by simulation of external and internal faults As per 5.15 3. Function Test & Scheme Check As per 5.4 4. Final Trip Test As per 5.11 5. On Load Test As per 5.23.4



TCSP105R01/TMA


4.21 Restricted Earth Fault (REF) Transformer Protection (64NP / 64NS)




1. General Electrical Test As per 4.2 & 4.3 if applicable

2. Check Pick-up \ drop-off voltage and corresponding current by injecting voltage for all available adjustable settings.

3. Non linear resistor (NLR) characteristic test.

4. Ensure that the error percentage between set value and actual value within the acceptable limit.



1. Final Setting as per approved setting 2. Stability & Sensitivity Test by simulation of external and internal faults As per 5.16 3. Function Test & Scheme Check As per 5.4 4. Final Trip Test As per 5.11 5. On Load Test As per 5.23.5



TCSP105R01/TMA


4.22 Over/Under-Frequency & Frequency Rate of Change Protection (81/81R)



4.22.2 Over/Under Frequency Protection Relay Electrical tests ITEM DESCRIPTION REMARKS


if applicable

2. Check f>, f< Pick up & drop off for all stages and for selected various adjusting setting values.

3. Check f>>, f<< Pick up & drop off for all stages and for selected various adjusting setting values.

4. Check time settings for all stages and for all frequency functions (f<, f>, f>>&f<<)

5. Check frequency rate of change for all stages.(df/dt) 6. Check Blocking pickup and reset for Under voltage condition.

7. Check applied voltage with measured voltage on relay display screen if applicable (for digital relays).






TCSP105R01/TMA


4.23 Automatic Voltage Regulation & Control (90)






2. Check the line drop compensation. 3. Regulating Value ∆U % Test. 4. Circulating current Test if applicable. 5. check of voltage levels

6. Check the effect of load shedding enable and the effect at various settings.

7. check of linear time delay 8. Check of inverse time delay. 9. Raise & Lower command time delay measurement. 10. Over and under voltage blocking test. 11. Over current blocking test.




1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.5 3. On Load Test



TCSP105R01/TMA


4.24 Disturbance & Fault Recorders (DFR)




2. Check the DFR name plate information for compliance to approved drawings and equipment/ material list.

3. Check the printer, PC work station, and monitor if available.

4.24.2 Electrical Tests ITEM DESCRIPTION REMARKS

1. General Electrical Test As per 4.2 & 4.3

if applicable

2. MEASURE A/D REF. BETWEEN TERMINALS.

3. Ensure that the T/line parameters for DTF feature (if applicable) are available at site.

4. Check the communication channels from the DFR to the destination (printer, backup hard disk, PC workstation, other DFR, …etc)

5.

Check the configuration of the Disturbance Fault Recorder for following Input Channels as per allocation. (A) Analogue Input Channels

a. Current Channels b. Voltage Channels c. Frequency Channels

(B) Digital Input Channels d. Binary / ON-OFF input Channels.

Configure: - Channel Type - Channel Name

6. Check the calibration of Analogue Input Channels

a. Off Set or Zero Adjustment b. Gain adjustment

7.

a. Trigger Test for input Channels one by one. i. Digital Input Channels one by one. ii. Analogue Input Channels (sensor trigger) Current Channel over Trigger Test at 110 % and 150%of rated

current and Final Trigger setting at 110% for Line currents and at 40% for Residual/ Neutral currents.

Voltage Channel under Trigger Test at 75% and 90% of rated voltage and Final trigger setting at 90%.

Frequency settings under & over trigger Test at 59.8 and 60.2 Hz respectively. Final trigger setting at 60.2 Hz.

b. Trigger By network from another DFR (cross trigger).

8. Check the record of triggered inputs in the Disturbance Fault Recorder and compare.

9. Check different record types & Scales a. Continuous slow scan b. Fault / Disturbance Record



TCSP105R01/TMA



10. Check availability of spare channels for future extensions. Depending on

contract.



1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11

(Check fault recorder event triggers are received correctly during trip test)

4. End to End test As per 5.18, 5.17 (Check fault recorder event triggers and carrier received are received correctly during end to end test)



TCSP105R01/TMA


4.25 Sequence of Events Recorder (SOE)



2. Check the Sequence Of Event recorder name plate information for compliance to approved drawings and equipment/ material list.



1. General Electrical Test As per 4.2 & 4.3 if applicable

2. Check the communication channels from the S.E.R. to the destination (printer, backup hard disk, PC workstation, …etc)

3. Check the configuration of the S.E.R. for digital Input Channels as per allocation. (Binary / ON-OFF input Channels.)

Configure: - Channel Type - Channel Name

4. Trigger Test for digital input Channels one by one. 5. Check the record of triggered inputs in the SER and compare.

6. Check availability of spare channels for future extensions. Depending on contract.


ITEM DESCRIPTION REMARKS 1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11

(Check event recorder event triggers are received correctly during trip test)

4. End to End test As per 5.18, 5.17 (Check event recorder event triggers and carrier received are received correctly during end to end test)



TCSP105R01/TMA


4.26 Annunciator (alarm module)



2. Ensure that all Annunciation Modules are properly identified as per the approved drawings and relevant SEC standards and that the identification does not obscure information displays.

3. Check for the correct writings (litra) of alarms. 4. Check for the correct color coding for trip / non-trip alarms.

5. Check the total number of annunciator windows it should have a 10% spare provision for urgent and non-urgent alarms.




if applicable 2. Check the Lamp Test and confirm that all indications are lighted up.

3. Check all applied settings are according to approved settings in schematic drawings.

4.

Test all the alarms and check silence, acknowledge and reset functions. a. Alarm indication lamp flashes on receipt of alarm. b. Pressing Acknowledge does not reset the alarm. c. Alarm does not reset until Reset is pressed.

5. Check annunciator regulated alarm output voltage.

6. Check dual supply operation by disabling primary and back-up supplies one at a time, and check relay indication for supply healthy/fail.

7. Confirm the annunciator failure alarm to SCADA.


ITEM DESCRIPTION REMARKS 1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.10 3. Final Trip Test As per 5.11

(Check trip alarms during trip test)

4. End to End test As per 5.17, 5.18 (Check alarms during end to end test: Trip, Lockout, Auto re-closer, fault recorder, communication failure, communication received)



TCSP105R01/TMA


4.27 Transducer

4.27.1 Mechanical Checks, Visual Inspection ITEM DESCRIPTION REMARKS

1. General visual inspection As per 4.1



2. Verify that the transducer output range is compatible with the RTU input setting.

WATT TRANSDUCER Inject the transducer with current and voltage at 20,50,75&100% rating varying the injection angle from 0,90,180,270º

1. Check the Input Watt and output Ratio error at Different Current and Voltage levels.

2. Check the Input Watt and output Ratio error at Different Power Factor values and Angles.

VAR TRANSDUCER Inject the transducer with current and voltage at 20,50,75&100% rating varying the injection angle from 0,90,180,270º

1. Check the Input VAR and output Ratio error at Different VARs.

2. Check the Input VAR and output Ratio error at Different Power Factor values and Angles.

VOLTAGE TRANSDUCER Inject the transducer with voltage at 20, 50, 75&100% rating.

1. Check the Input and output Ratio error at Different Voltage Values. CURRENT TRANSDUCER Inject the transducer with current at 20, 50, 75&100% rating.

1. Check the Input and output Ratio error at Different Current Values. FREQUENCY TRANSDUCER Inject the transducer with voltage with varying the frequency at 20, 50, 75&100% rating.

1. Check the Input Frequency and output Ratio error at Different Frequency Values.

2. Check input signal proportional to the output dc signal Test.

3. Check the connections according to manufacturer's standard connection procedure



TCSP105R01/TMA


ITEM DESCRIPTION REMARKS WATT-HOURS TRANSDUCER Inject the transducer with current and voltage at 20,50,75&100% rating varying the injection angle from 0,90,180,270º For a duration of 15 minutes minimum.

1. Check the accuracy of watt-hour Meter. 2. Check the polarity of the potential transformer. 3. Check the polarity of the current transformer.

4. Check the connection of the potential and current circuit base on manufacturer’s standard procedure.

VAR-HOUR TRANSDUCER Inject the transducer with current and voltage at 20,50,75&100% rating varying the injection angle from 0,90,180,270º For a duration of 15 minutes minimum.

1. Check the accuracy of VAR-hour Meter 2. Check the polarity of the potential transformer 3. Check the polarity of the current transformer

4. Check the connection of the potential and current circuit base on manufacturer’s standard procedure


ITEM DESCRIPTION REMARKS 1. Final Setting as per approved setting


TCSP105R01/TMA



4.28 ACSE / ABTS / TOP.

Automated Bus Transfer Scheme (ABTS) - Auto Changeover Switching Equipment (ACSE) - Trip on Parallel (TOP)

4.28.1 General Mechanical checks and visual inspection ITEM DESCRIPTION REMARKS 1. As per 4.1General Visual Inspection

Check the communication channels like Profibus, Modbus, and Ethernet etc are working.

2.



General Electrical Test As per 4.21. & 4.3 if applicable

2. Check the indications of PLC working OK. 3. Check the Schematic diagram for Automatic Control Schemes. 4. Check the different combinations of Schemes.

Check the conditions for closing standby breaker (bus coupler or incomer) a. Check Synchronizing between the Buses. b. Be sure all Circuit Breakers are in service and in Remote Position.

5. c. Be sure that all Potential Transformers are in service. d. All the Potential Transformers MCB's are ON. e. ABTS / ACSE are on and in service.

(As per the approved scheme and protection requirement)

Check the Blocking conditions of standby breaker (bus coupler or incomer) from closing during following conditions: a. Sensitive Earth Fault operation. b. 132 KV or 110 KV or 13.8 KV Bus Bar Differential Relay operations. c. ABTS off or out position.

6. d. If Bus Section over Current works. e. Manual opening of CB f. Overload conditions: Transformer LV O/C or Transformer winding

temperature protection operated. g. Transformer high side time over current. Prove scheme for opening of bus section breaker to break parallel of three transformers is functioning.

7.

8. Operation of all alarm, SCADA and SOE outputs from the panel. If applicable. 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).

9.


4.28.3 Related Tests ITEM DESCRIPTION REMARKS 1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.8


4.29 ACCS – Automatic Capacitor Control System

4.29.1 Visual Inspection



Check the communication channels like Profibus, Modbus, and Ethernet etc are working.

2.



ITEM DESCRIPTION REMARKS General Electrical Test As per 4.2

1. & 4.3

if applicable Check that rating of the PLC of ACCS agrees with the Auxiliary Supply to which it is connected.

2.

Manufacturer should be submitted ACCS configuration to SEC and approved.

3.

Check PLC applied configuration according to approved configuration, schematic drawing and operation requirement.

4.

Check the Schematic diagram for ACCS Schemes according to single line diagram and protection requirement.

5.

Ensure that all ACCS setting can be changed from HMI of ACCS and the setting saved without changed if DC supply is switched off.

6.

7. Perform PLC self-test procedure and external communications checks.Ensure that the ACCS mimic diagram for panel and HMI are matching with actual switch gear panels and single line diagram of approved drawings.

8.

Check all PLC binary inputs and PLC outputs, INDICATION LEDs, alarm indication messages on HMI, event & fault recorder and Annunciation. All checking should be according to schematic drawing to check breakers status, several conditions and expected actions.

9.

Check Automatic switching ON and OFF of the capacitor banks shall be based on 1- Reactive Power measurement 2- Voltage measurement on respective busses 3- Power Factor

10.

Check and measure setting of Over Voltage, Under Voltage, Leading power factor, Under MVAR, Over MVAR. And Verify For ACCS Secondary injection measurements by Injected Voltage and current and ensure that the error percentage between HMI reading and injected value for Voltage and reactive power and power factor with in the acceptable limit.

11.

Check all interlock circuit and elapse times for capacitor are as per approved drawing and ACCS configuration and settings.12.


TCSP105R01/TMA



ITEM DESCRIPTION REMARKS Checking of the ACCS SCHEME: Check status of all related circuit breakers, devises, equipments and protective relays for each case. Check LEDs, display messages and alarm annunciations settings for each case.

13.

Ensure that all interlock circuit for capacitor is as per approved drawing and ACCS approved configuration. Measure all time settings in PLC configuration for all cases.



1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.9


5. PROCEDURE FOR SCHEME AND FUNCTIONAL CHECKS

193 5.0 PROCEDURE FOR SCHEME AND FUNCTIONAL CHECKS194 5.1 General Panel Function Tests196 5.2 Local Control Cubicle (LCC) Panel Function Test198 5.3 Relay & Control Panel Function Test203 5.4


Transformer Function Test 205 5.5 Automatic Voltage Control Panel Function Test206 5.6 Load Shedding & Under Frequency Panel Function Test207 5.7 Bus Bar Protection Panel Function Test208 5.8 ACSE / ABTS / TOP Function Test209 5.9 ACCS – Automatic Capacitor Control System211 5.10 Common Alarms Panel Function Test and Alarm Scheme Test212 5.11 Final Trip Test213 5.12 Synchronizing Relay 215 5.13 Bus Bar Protection Stability & Sensitivity Test217 5.14 Stuck Breaker Protection Stability & Sensitivity Test220 5.15 Transformer Differential Protection Stability & Sensitivity Test222 5.16 Restricted Earth Fault Protection Stability & Sensitivity Test224 5.17 End To End Test for Over Head Line Feeders229 5.18 End To End Test for Under Ground Cable Feeders230 5.19 SCADA Point List checking 230 5.19.1 SCADA Commands Tests230 5.19.2 SCADA Back Indication Tests230 5.19.3 SCADA Alarms Tests 231 5.20 Metering and Readings through SCADA to ECC232 5.21 Pre-Energization Confirmation Checks233 5.22 During Energization Confirmation Checks235 5.23 On Load Tests 235 5.23.1 On Load tests for CT/VT Circuits & Transformer Inspection. 235 5.23.2 On Load Line/Cable Differential Protection Stability & Sensitivity 236 5.23.3 On Load Confirmation of Relay Directionality237 5.23.4 Transformer Differential Protection on Load Stability Tests 238 5.23.5 Restricted Earth Fault Protection on Load Stability Tests238 5.23.6 Bus Bar Protection on Load Stability Tests238 5.23.7 Stuck Breaker Protection On-Load Stability & Sensitivity Tests 239 5.24 Recommended Test Equipment



5.1 General Panel Function Tests

ITEM DESCRIPTION REMARKS Before testing

a. Approved commissioning copy schematic drawing shall be pre-checked.

b. All secondary injection and all components tests shall be completed and witnessed. All test results must be available and signed. 1.

c. Auxiliaries, timers, contactors, pulse units, annunciators, MCB’s … etc.

d. All final settings applied as appropriate (timers, pulse units, annunciators) shall be applied and witnessed.

20% of all auxiliary relays, timers, contactors, pulse units, annunciators, MCB’s … etc, should be tested and witnessed.

2.

Verify that each supply is wired point to point, with no unsupervised 3. branches. Supervision is checked by wire removal at every point in the

circuit to make sure the supervision flag drops. 4. Check that the ability to access to every equipment terminal is easy

Check DC source and DC loops (control, interlock & power supply) according to the schematic drawings.

5.

Check DC Segregation for opening / tripping circuit, closing circuit, & alarm circuit.

according to the schematic drawings

6.

Check AC and DC MCB's ratings grading. according to the schematic drawings

7.

Check the supply change over function. according to the schematic drawings

8.

Check AC source and AC loops. according to the schematic drawings

9.

Check the thermostat and the heaters. according to the schematic drawings

10.

Check the AC lamp,DC lamps and door switch and Check lamp test for all equipment

according to the schematic drawings 11.

Check AC socket. according to the schematic drawings

12.

13. Check the ferrules as per specification. 14. Check the labels.

Check DC supervision. according to the schematic drawings

15.

Check AC supervision. according to the schematic drawings

16.

Check the alarm signal to SCADA, Mosaic panel (control panel), Alarm panel, Protection panel, fault recorder including equipment fail and watchdog alarms.

according to the schematic drawings 17.

All control, protection, metering and signaling equipment shall be capable of satisfactory operation at an indoor ambient temperature of 55°C.

18.

Check cable into control kiosk /cubicles/panels are properly sealed or glanded and terminated on suitable terminals in kiosk.

19.


TCSP105R01/TMA



ITEM DESCRIPTION REMARKS 20. Check panels earthing as per specification. 21. Check cables for proper shielding and grounding

Check proper Terminal Block arrangement and labeling: As per relevant SEC specifications a. Shorting & Isolating for CT circuits

b. Isolating for VT circuits 22. c. Solid Type for control circuits

d. Trip Isolation facilities where needed e. Solid type with spring loaded for trip circuits f. Knife type for alarms

23. Check that heat sources such as external resistors are covered with suitable covers and far away from panel wiring.

24. Check that CT and VT circuits are facilitated with suitable covers and caution labels for protection.

25. Ensure availability of proper test facility depending on the type of protection or metering equipment:

Shorting test facility for current circuits Isolating test facility for voltage circuits Trip and Alarm isolation when relays are being tested

26. Check that caution labels and caution clauses in the schematic drawing are included to prevent accidental on-load opening of CT circuits.

Shorting before isolation

27. Check the availability of proper panel lighting controlled by a door switch and electrically connected to the emergency DC supply as well.

28. Check Color coding of panel wiring as per relevant specification 29. Check that at least 10% spare cable cores are provided and terminated at

the terminal blocks farthest from the cable entry.

30. Check that percent (10%) spare terminals shall be provided on each terminal block.

31. Check that ten percent (10%) spare alarm windows are available for future modifications

32. Check that terminal blocks are grouped according to function, i.e. Power Supplies (AC or DC), VT, CT, DC controls, annunciation, SOE, SCADA etc. and shall be labeled accordingly. Terminal blocks for different voltages (AC or DC), CT, PT shall be located separated DIN rails.

33. Check that the physical wiring matches the schematic drawings and that any difference between scheme and implementation or correction in interface points is marked up in green and red ink.

34. Check wire rating, color coding, cross section, ferruling, trip markers ('T') and DC supply markers ('+' , '-')

35. Protective shrouds on high voltage areas in the panel such as CT terminal blocks with caution labels, protective shrouds on exposed resistors for high impedance protection relays, protective shrouds on metrosil's for REF … etc


5.2 Local Control Cubicle (LCC) Panel Function Test

5.2.1 General Mechanical checks and visual inspection ITEM DESCRIPTION REMARKS 1. General Visual Inspection As per 4.1

Panel condition, cleanliness, organization, labeling, readiness for service, panel doors, handles...etc

2.

3. CT shorting checked 4. Indications checked 5. Contact resistance of tripping and alarm checked


ITEM DESCRIPTION REMARKS 1. General Function Tests As per 5.1

Check proper arrangement and labeling of all bays and compartments in the mimic diagram on the LCC panel, and that these labels agree with the switchgear layout, the mimic panel in the control room and the approved drawings.

2.

Check proper labeling and arrangement of gas and hydraulic diagrams on the LCC panel.

3.

If withdrawable circuit breakers are used for isolating purposes then indication of circuit breaker “service”, “test” and “withdrawable” positions shall be provided on the panel and connected to SCADA interface panel.

4.

Check All panel alarms, initiated from the main source (contact of gauge, breaker...etc) to all destinations (control room , common alarm panel, LCC Annunciator , SCADA)

5.

Make sure that all mechanism compartments are easily accessible and properly arranged for future maintenance or inspection.

6.

Check local (Switchgear mechanism compartment and LCC panel) and remote (control room and SCADA back indication) equipment position indication of all switchgear, including half way position indication at test and service positions according to approved schematic drawings..

7.

Check the flickering indication of DS/ES during moving including half way position indication at test and service positions according to approved schematic drawings.

8.

Operation Check the function of circuit breakers ( open – close – trip1 – trip2) Local &

remote1 9.

Check CB Anti Pumping Function / Trip Free Function at local and remote position) and ( at test and service position) Step 1: Ensure Gas, Air and DC Supply is normal for the CB under test.

10. Step 2: Close the Breaker Electrically and Hold the Control Switch in ‘CLOSE’ position.

Step 3: Trip the Breaker by Externally extending the DC Supply to Trip Circuit. (Not by any trip relays which


is used for close interlock)


TCSP105R01/TMA




Step 4: Observe the Breaker to ‘TRIP’ and remain in ‘OPEN’ position & does not close.

Step 5: Thus Anti Pumping function found working with the above sequence.

11. Check CB Anti-Slam Function 12. Check the function of lock switch and emergency switch of each

component according to schematic drawing.

13. Check the function of the isolators and earth switches ( open – close) Local & remote

Check local and remote (from control room & SCADA) operation of CB, DS, ES.

14.

Check the all auxiliary contacts (52-a /52-b) of the circuit breaker and the DS / ES

15.

16. Check breaker closing/ tripping blocking e.g. for SF6 low stage 1 / stage 2 Interlocking

Check that the interlocking schedules are approved and revised by operation department.

17.

Checks the interlock circuit compared with the approved drawing and ensure also that there are interlock between mechanical and electrical operation.

18.

Check that the interlock circuit is normally blocking even with DC failure. In the design of the scheme continuously energized relays shall be avoided as far as possible. It shall operate in a “fail-safe” mode by ensuring that interlock release conditions are established only by energizing a relay or relays.

19.

Ensure that lockable switch is provided at each local control kiosk to manually over-ride the interlocking for that switchgear bay.

20.

Ensure that Manual operation of all earthing switches and maintenance earthing devices is only possible under electrical interlock release conditions.

21.

Check operation blocking during half way position or disconnector / earth switch failure.

22.

For withdraw-able circuit breakers check mechanical interlocking between earth switches and breaker rack-in rack-out operation.

23.

Check mechanical interlocking conditions as per approved interlock diagram.

24.

Check proper operation of de-interlocking selector switch and ASSURE the lock ability of this selector if available.

25.

Check CB Close block conditions for example permanent faults (lockout operated) or GIS malfunction (insulation medium low).

26.


5.3 Relay & Control Panel Function Test

5.3.1 General Mechanical checks and visual inspection ITEM DESCRIPTION REMARKS 1. General Visual Inspection As per 4.1

Panel condition, cleanliness, organization, labeling, readiness for service, panel doors, handles...etc

2.



ITEM DESCRIPTION REMARKS 1. General Electrical Tests for Protection Relays As per 4.2


& 4.3 2. General Function Tests As per 5.1

Trip circuit supervision

Verify integrity of individual trip circuit supervision, including pre-closing and closed CB supervision. Make sure wiring is made point to point with no branched connections to make sure that all trip supplies are supervised 3.

Disable Trip circuits individually and verify that the other circuit is healthy and operable. Trip circuit supervision should have indication on both the control panel and in the alarm scheme

Verify tripping arrangement as per approved schematic drawings, example:

As per approved scheme

a. First main protection to trip on circuit 1 4. b. Second main to trip on circuit 2 c. Bus bar protection or breaker fail or Transformer differential

protection to trip on both TC1 and TC2 Check wiring for bus bar protection loop and CBF relay, check CBF supply is ok, check CBF initiation from all trip relays, and that all trips (even mechanical trips) initiate trip relays, which then initiate the CBF.

5.

When specified, the relay panel should incorporate proper In/out facility: Locally or remotely operated (SCADA) Indication and or Alarm of the status of the protection (in or out)

6. Disconnecting alarm and trip contacts when in out position Bus-bar zone out of service will still trip depending on check zone (for discrimination zone out), or depending on discrimination zone (for check zone out of service) Verify the use of close blocking lockout relays and auto resetting trip relays is as per scheme depending on the type of protection operated.

7.

Mimic & Indication 8.

Verify that the mimic diagram and equipment labeling is correct and



TCSP105R01/TMA



matches the switchgear layout, the LCC panel, and the approved drawings. Verify that the indication in the mimic panel matches the indication in the LCC panel and the actual position of CB/DS/ES is it open, closed, moving (flickering), or middle position (flickering). Availability and operation of lamp test switches

9.

Local Remote Operation

Check the discrepancy switches for proper operating (open, close) and check their contacts arrangements to match the schematic drawings for number of contacts and type of contact (NO, NC) Check the availability of lockable local/remote switches and check local and remote commands of the switch gear from the control panel and SCADA and ensure that the electrical interlocking is maintained for remote operation of the switchgear from the mimic/control panel. Check all operating loop contacts/conditions for SCADA commands individually including necessary interlocks, SF6 low, close block, …etc Check commands and back indication with SCADA interfacing panel.

10.

Metering

Check that meters are available in the correct scales for the rating of the equipment and that they have been tested and final set (for digital equipment) correctly and are properly labeled. Check availability of proper test facility for testing of panel meters, this facility MUST have proper polarity wiring for accurate testing.

11.

Synchronizing panel:

Verify the required conditions to connect the voltage transformers of selected feeder to the Synchro-check system Verify synchronizing interlock such as: Following selection of synchronize operation on the feeder, selection on any other feeders shall be prevented until the system has reset. MCB trip for the required P.T shall prevent synchronizing system operation Verify C.B closing with automatic synchronizing from local and SCADA, also check manual synchronizing Check the function of the bypass selector switch from SCADA and local. Check operation of indication & alarm lamps.

As approved schematic drawing

12.

Check that alarm and also a visual indication shall appear on the substation central signaling system and the signal shall also be wired with a potential free N.O. contact to the SCADA interface cubicle for transmission to LDC.

13. Check that alarm system failure contacts initiates alarm to SCADA

14. Check that all substation support systems (communication equipment, battery room MCB's, Battery chargers, Fire protection, HVAC control

As per approved alarm



TCSP105R01/TMA



panel …etc) are incorporated in the substation general alarm scheme. list or relevant

alarm specification.

15.

Check that successful AC or DC automated bus transfer does not initiate any AC or DC supply fail alarms (that AC and DC fail alarms are non latching and that annunciator time setting is compatible with ATS change over settings).

16. Check proper time and color setting for alarms (trip and non trip / urgent and non-urgent) as per alarms specification.

17. Check zone selection for BB protection loop depending on isolator position.

18. Bus bar trips and trip conditions (by simulation from the source panel (bus bar panel)

5.3.3 Electrical test for numerical control relays panels.



2. Devices that have multiple standards of characteristics to be tested as per SEC used standards (example IEEE standard curves for Over-Current Time Inverse characteristics)


4.


Ref IEC 61850-5 , Clause 13.7.4


6.

Communication channel test (one way total communication delay time, bit error rate)






TCSP105R01/TMA



9.




Ref IEC 61850-10, Clause 6.2.4.16.1


Ref IEC 61850-10, Clause 6.2.4.16.2



15. Verify that the final configuration of the relay is fixed and not accessible without proper software or authorization.


16. Check Relay configuration and interface with PC.

17. Ensure that relay Disturbance Fault recorder & internal event recorder are working properly.


19. Any testing performed to digital or electronic equipment requires the use of proper antistatic gear (anti-static mat, anti static wrist guard) for anyone in contact with the equipment.

20. Mimic and single line diagram on the relay display has to be checked according to approved single line diagram of SS

21. Control configuration and all functions of the relay have to be checked according to approved schematic diagram and approved configuration.

22. Interlocking logics have to checked and studied according to approved scheme and conditions.

23.

Check of all breaker, disconnector and earth switch positions. The position indications are checked by local operation in the field and the physical position of every device has to be compared with the shown position on the local mimic, the displays of the relays and on the SAS.

24.

Check of all breaker, disconnector and earth switch commands. The commands have to be checked for the possible modes (Local, Emergency & Remote.). Local operation mode at the relay display can be selected by selector button on the relay display. Every switching devices has to be operated (open and close) in the local mode. Remote mode at SAS at the relay display can be selected by selector button on the relay display. Every switching devices has to be operated (open and close) in the remote mode.


TCSP105R01/TMA




25. The proper LED indication has to be checked. The interlocking logic for local and remote operation can be either checked

from locally from relay display or remotely from SAS. These conditions have to be checked according to the approved base design document. Eventually the system contains an interlocking override function which has to be checked by the certain instance (e.g. Mimic, UBC or SAS.)

26.

Checking of close blocking by lock out relay. 27. Checking of synchrocheck function. 28. Check of measurement. 29. 30. Check of automatic voltage regulator. 31. Check of alarm panel.

Remark:

Substation automation procedures must be submitted from suppliers at least 6 months before starting commissioning for study by SEC.


5.4 Transformer Function Test

5.4.1 Transformer Relay & Control Panel Function Test

a. General Mechanical checks and visual inspection ITEM DESCRIPTION REMARKS 1. General Visual Inspection As per 4.1

b. Electrical tests ITEM DESCRIPTION REMARKS

A General checks

1. General Function Tests As per 5.1 2. Relay & Control Panel Function Tests As per 5.3

B Protection Panel Check

Verify the distribution of main and backup protections on the protection supplies( R1,R2,R3,R4)

1.

Verify that the Mechanical protection tripping by simulation from the source contact for EVERY mechanical protection from the source (from the protection device itself, not from the GTMK panel and not from the TX panel).

2.

C Control Panel Check

Mimic has to be ok, color coding for HV, MV, and tertiary if applicable for single line should be correct.

1.

Check interlocking between isolators and breakers and between HV and MV breakers (test / service conditions)

2.

D Fire Protection Panel Check

DC supply and supervision for supplies shared between the relay panel and the fire protection control panel.

1.

Verify proper interfacing between fire protection scheme and transformer protection scheme:

According to approved schematic drawing and protection requirement

2. Trip both sides of the transformer Disconnect Transformer cooling fan motors Initiate water spray system in the Transformer Room Assure the connection fire protection alarm scheme to the substation alarm scheme for fire protection ready, healthy, operated, water low …etc

3. Ensure that alarms are received at the Transformer control panel annunciator and reaching to SCADA.


TCSP105R01/TMA



5.4.2 Transformer Marshalling Kiosk (GTMK) function test

a. General Mechanical checks and visual inspection ITEM DESCRIPTION REMARKS


b. Electrical tests

ITEM DESCRIPTION REMARKS 1. General Function Tests As per 5.1

Check the operation of Fans automatic, manual, local and remote positions.

2.

Verify trip commands for transformer mechanical protection relays (Buchholz relay, Over Temperature protection, etc)

3.

Check the supply changeover for fan motor circuit during: 4. AC MCB trip

Main source failure (under-voltage condition) Ensure that spare CT cores for bushing CT's and NER CT are wired to the GT-MK panel and shorted and earthed using proper short/isolate facility

5.


5.5 Automatic Voltage Control Panel Function Test


1. General Visual Inspection. As per 4.1


1. General Function Tests As per 5.1


, 5.2 Ensure that all standard electrical tests of PT that feeds AVR by voltage signal are done.

2.

Ensure that all standard electrical tests of CT that feeds AVR by voltage signal are done (if CT applicable).

3.

Ensure that the phase sequence of voltage which starts from PT secondary to AVR is correct.

4.

Ensure that the phase sequence of current which starts from CT secondary to AVR is correct (if CT applicable).

5.

Check that the Remote Tap Position Indicator matches the indication on the Local Tap Position Indicator and the indication sent to SCADA

6.

Check local operation interlocking for Raise & Lower commands depending on Local / Remote and Auto / Manual Selector switches.

7.

Check remote operation interlocking for Raise & Lower commands depending on Local / Remote and Auto / Manual Selector switches.

8.

Check that Raise & Lower commands to the tap changer are blocked during tap changer operation for manual commands and that AVC delay time setting is greater than tap changer step time.

9.

10. Check panel indication for tap change in progress Ensure that all OLTC alarms are wired to the AVC panel and incorporated in the alarm scheme (to SCADA) (OLTC AC / DC fail, tap changer out of step, OLTC Buchholz, etc...)

11.

12. If applicable, check remote operation of transformer fans. 13. Check the operation of load shedding (if applicable) from SCADA.

Check SCADA control and back indication of Auto/Manual voltage control scheme.

14.

15. Check master / follower scheme if applicable.



5.6 Load Shedding & Under Frequency Panel Function Test





As per 5.1


1. General Function Tests , 5.2

2. Check the trip matrix of the frequency relay for each stage. Check the trip matrix of the under-voltage relay for each stage (if applicable)

3.

4. Check the Voltage Change over Scheme.



5.7 Bus Bar Protection Panel Function Test




As per 5.1


1. General Function Tests , 5.2

Verify the CT switching scheme and proper zone selection if hardwired. For digital protection schemes, verify the relay’s internal bus-bar replica and zone selection is correct including bus merge / load transfer conditions.

2.

Check Bus-bar trip logic / conditions from the relay up to the circuit breakers

3.

4. Test In / Out operation for each check zone & discrimination zone Test trip logic for each zone out: Discrimination zone out = 1 out of 1 tripping based on check zone operation.

5. Check zone out = 1 out of 1 tripping based on discrimination zone operation. Both CZ and DZ out = no tripping for that bus zone. CBF supply and supply supervision if supplied through the Bus-bar panels.

6.

7. Check CBF relay tripping through bus-bar panel bus replica scheme.



5.8 ACSE / ABTS / TOP Function Test

Auto Changeover Switching Equipment - Automated Bus Transfer Scheme - Trip on Parallel Scheme



1. General Visual Inspection. As per 4.1



1. General Function Tests. As per 5.1


, 5.2 2. Study the different schemes for automatic closing of the standby or the

parallel running Transformer incomer Breakers or Bus section in case of tripping of any transformer available in the Schematic diagram.

3. Study test format compared with schematic drawing and protection requirement.

4. Check status of all related circuit breakers, devises, equipments and protective relays for each simulation case.

5. Check 4 out of 5 interlocking scheme is achieved while DC loss of PLC device.

6. Simulate operation cases one by one according to test format and record results. (Check the Schemes by tripping of the different transformers one by one and changeover of the switchgears are according to the Scheme.)

Check the blocking of Changeover for the Blocking Conditions of Auto Changeover of Switchgears. Check the Scheme opening of Bus Couplers or Incomers in case of energization of tripped Transformer.

7. Check LEDs, display messages and alarm annunciations for each simulation case.

8. Check all cases and conditions at ACSE/ABTS ON and ACSE/ABTS OFF positions.

And check all cases and conditions at TOP ON and TOP OFF positions. 9. Check all cases and conditions at control mode and ECC mode and

segregation between each other.

10. Measure all time settings in PLC configuration. 11. Check panel indication for:

ACSE/ABTS ready ACSE/ABTS close command failed TOP scheme selected




ITEM DESCRIPTION REMARKS 1. General Visual Inspection. As per 4.1

Check current transformer circuits and voltage transformer circuit are connected to the ACCS correctly as per approved drawing.

2.



1. General Function Tests As per 5.1


, 5.2 Check all related CT's, VT's, circuit breakers, auxiliary relays, protection relays and metering devises were tested.

2.

Check that rating of the PLC of ACCS agrees with the Auxiliary Supply to which it is connected.

3.

Manufacturer should be submitted ACCS configuration to SEC and approved.

4.

Check PLC applied configuration according to approved configuration, schematic drawing and operation requirement.

5.

Check the Schematic diagram for ACCS Schemes according to single line diagram and protection requirement.

6.

Ensure that all ACCS setting can be changed from HMI of ACCS and the setting saved without changed if DC supply is switched off.

7.

8. Perform PLC self-test procedure and external communications checks. Ensure that the ACCS mimic diagram for panel and HMI are matching with actual switch gear panels and single line diagram of approved drawings.

9.


10.

11. Check of test and measuring instruments calibration certificates. Verify For ACCS Secondary injection measurements by Injected Voltage and current and ensure that the error percentage between HMI reading and injected value for Voltage and reactive power and power factor with in the acceptable limit.

12.

Automatic switching ON and OFF of the capacitor banks shall be based on 1- Reactive Power measurement 2- Voltage measurement on respective busses 3- Power Factor

13.

The testing should be done sequentially using the proceeding tables with all the preliminary settings. Using a 3 phase injectors for voltage, current and power factor for each transformer, each case and mode of operation should be simulated and verified according to the setting.

14.

The Common operational mode like Over Voltage, Under Voltage, Leading power factor, Under MVAR, Over MVAR should be Simulated in each cases above at ON position and OFF position and TEST position.

15.



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16. The Common operational mode like Over Voltage, Under Voltage, Leading power factor, Under MVAR, Over MVAR should be Simulated in each cases above at LOCAL position and SCADA position.

17. The Common operational mode like Over Voltage, Under Voltage, Leading power factor, Under MVAR, Over MVAR should be Simulated in each cases above at AUTO position and MANUAL position.

18. Ensure that all interlock circuit and elapse times for capacitor are worked properly as per approved drawing and ACCS configuration and settings.

19.

Checking of the ACCS SCHEME: Check status of all related circuit breakers, devises, equipments and protective relays for each simulation case. Check LEDs, display messages and alarm annunciations for each simulation case. Simulate operation cases according to test format and record results. Ensure that all interlock circuit for capacitor is worked properly as per approved drawing and ACCS configuration. Measure all time settings in PLC configuration for all above cases.



TCSP105R01/TMA


5.10 Common Alarms Panel Function Test and Alarm Scheme Test



1 General Visual Inspection. As per 4.1


1. General Function Tests. As per 5.1 , 5.2

2. Study the schematic diagrams for alarm showing auxiliary contacts for operation of different equipments, relays or breakers.

3. Generate the alarms by removing wire or bypass (making jumper) the NC or NO contacts from the alarm source.

4. Check the alarms in the S.E.R. outputs, annunciation panel and the SCADA system at Remote Terminal Unit are in the same sequence as generated.

5. Check the alarm wording in the S.E.R. outputs, annunciation panel and the SCADA system at Remote Terminal Unit are correct and understandable.

6. Check the outputs on the resetting of alarms. 7. Check alarm scheme supply changeover

8. Check the alarm scheme for proper initiation of the common buzzer or horn from all connected annunciators in the control room.

9. Check alarm failure contacts to SCADA

10.

Check alarm windows for labeling, colors, and time delay settings for trip/non-trip alarms.

As per approved alarms organization

11. Check that any alarm 'sleep mode' selector switches are lockable type switches and check their operation.

12. Check lamp test facilities and silence, acknowledge and reset buttons for proper operation.


TCSP105R01/TMA



5.11 Final Trip Test ITEM DESCRIPTION REMARKS

1. Perform Tripping of Power Transformer Controlling Breakers through test contact of Buchholz Relay, OLTC Protective relay, Oil & Winding temperature protection.

2. Perform Tripping of Power Transformer Controlling Breakers through each Electrical Protection by closing tripping contacts through secondary injection on the protection relays above the final setting.

3. Perform Tripping of Shunt reactor Controlling Breakers through test contact of Buchholz Relay, OLTC Protective. relay, Oil & Winding temperature protection.

4. Perform Tripping of Shunt reactor Controlling Breakers through each Electrical Protection by closing tripping contacts.

5. Perform Tripping of Capacitor Bank Controlling Breakers through each Electrical Protection by closing tripping contacts.

6. Perform Tripping & Inter-Tripping of Controlling breakers of Feeders/Transmission lines through each protection installed by closing tripping contact through secondary injection on the protection relays above the final setting.

7. Perform Tripping of Controlling Breakers of Bus Bar Schemes through Bus Bar Differential Protection by closing tripping contact of the relay through secondary injection on the protection relays.

8. Perform Tripping & Inter –Tripping for Breaker Failures schemes through secondary injection on the CBF relay with simulated initiation from the source contact on every protection relay.

9. Perform Tripping of Bus Coupler/Sectionalizer by closing trip contacts of the relays installed through secondary injection on the protection relays.

10. Ensure that every protection operated (during secondary injection trip test) initiates CBF scheme and check indication & alarms.

11. Ensure that every protection trips through its desired trip circuit independently by disabling the other trip circuit before secondary injection.

12. Ensure that every protection operated (during secondary injection trip test) initiates FR and check FR massage.

13. For OHL /UGC protection ensure that every protection operated (during secondary injection trip test) initiates inter trip sending relay and check indication & alarms.

14. For OHL protections ensure that fast trip protection start A/R and delayed trip blocked A/R and check indication & alarms.

15. Ensure that both trip circuits are normalized at the end of the trip test.


5.12 Synchronizing Scheme Check


1. CAUTION:


remove all VT's terminals from VT terminal block in VT's boxes and separate all VT's terminals from VT loops. Assure that all VT's impossible to be fed back from secondary sides.

2. Check that all voltage transformers were tested. 3. Check that VT loop test were done. 4. Check VT data and voltage rating, and check MCB's rating. 5. a. Check VT's disconnectors opening alarms and their closing condition

in CB closing circuit.

b. Check that positions of MCB's which exactly supply the synchronizing scheme are included in CB's closing circuits.(according to scheme)

c. Check the line voltage loop by applying voltage from VT secondary terminal block of all bays one by one according to schematic drawing.

d. Measure voltage for all points in the loop. Check the switching points of any switch included in the loop at the close and open position. Check any relay contact included in the loop at the close and open status. Measure line voltage and bus voltage at synchronizing relays and read measurement values on relays displays and assure that there is line voltage only. Measure line and bus voltages at the synchronizing meters in synchronizing panels and assure that there is line voltage only.

e. Check that the only selected feeder for check its synchronization feeds line voltage to synchronizing meters panel.

6. Check the voltage supervision of synchronizing loop by removing voltage from all points one by one and check flag, indication, alarm, else.

7. a. Check VT's disconnectors opening alarms and their closing condition in CB closing circuit.


c. Check the bus voltage loop by applying voltage from VT secondary terminal block of all buses one by one according to schematic drawing. The status of bus coupler and bus section must be considered and synchronizing condition dependent on their positions must be studded and checked well.

d. Measure voltage for all points in the loop. Check the switching points of any switch included in the loop at the close and open position. Check any relay contact included in the loop at the close and open status. Measure line voltage and bus voltage at synchronizing relays and read measurement values on relays displays and assure that there is bus voltage only. Measure line and bus voltages at the synchronizing meters in synchronizing panels and assure that there is bus voltage only.

e. Check that only one voltage feeding synchronizing loop if the two bus disconnectors connected to tow bus bars ( load transfer)



TCSP105R01/TMA




9. Check the dead line dead bus condition for all bays. Try to close CB's of all bays in all possible conditions (test and service positions) from local and ECC.

10. Check the live bus dead line condition for all bays Try to close CB's of all bays in all possible conditions (test and service positions) from local and ECC.

11. Check the live line dead bus condition for all bays. Try to close CB's of all bays in all possible conditions (test and service positions) from local and ECC.

12. Check the live line live bus condition or all bays. Try to close CB's of all bays in all possible conditions (test and service positions) from local and ECC.

13. Check the synchronizing condition for automatic recloser scheme if applicable.



TCSP105R01/TMA


5.13 Bus Bar Protection Stability & Sensitivity Test


1.

The following activities should be completed before start the bus bar stability test

a. Secondary injection for bus bar protection relays b. Final Settings Applied for the bus bar protection relays. c. Function Tests and scheme check for Relay and Control Panels (for

proper command and indications). d. Function Tests and scheme check in GIS (for proper operation of

the breaker) e. Proper Operation of Bus-bar Protection and Circuit Breaker Fail

schemes f. CT loop test, CT primary Injection & Single earthing point checked. g. Confirm that the single earthing point at the relay panel. h. Confirm that all associated CT cores are having the same Knee

point nearly. i. Check that all circuit breakers which needed to close loop are closed

according to single line diagram.

2. Caution: Check that any high impedance protection (ex. Transformer

REF protection) is shorted before primary injection on their CT Cores.

3. Caution: Any CT cores not related to bus-bar protection should be

shorted for safety.

4. Caution: During sensitivity test the CT supervision relay may operate,

the test plug should be putted in its test socket to prevent CT shorting during the testing and measuring currents.

5. Caution: The injected current should not exceed the smallest turns ratio

CT.

6. Caution: Check that all safety precautions from electric hazard was

taken as surrounding the testing area by caution tap, … etc.

7.

Inject primary current (5% of rated current) and Measure currents and their angles in BBP current circuit of the two bays which is under test (in LCC, BBP discrimination zone panels according to BB disconnector which is connected & check zone panel). Compare between currents and angles values to achieve stability. Measure the voltage across (CT supervision relays – differential relays – resistors – metrosil) for high impedance BBP or check measurement readings for low impedance digital relays.

8. Check stabilizing current Is and differential current Id values in digital differential relays Differential current Id should be zero.

9.

For sensitivity test, reverse the CT polarity of one bay and measure currents & their angles in BBP current circuit of the two bays which is under test (in LCC, BBP discrimination zone panels according to BB disconnector which is connected & check zone panel). Before injecting the current the cautions must be considered. Measure the voltage across (CT supervision relays – differential relays – resistors – metrosil) for high impedance BBP. Check the proper bus bar zone which shall be operated



TCSP105R01/TMA



10. For sensitivity test, reverse the CT polarity and check stabilizing current Is and differential current Id values in digital relays. Check the proper bus bar zone which shall be operated.

11. Repeat the previous steps with another bus bar disconnector is closed for reference and test feeders

12. Repeat the previous steps with load transfer and keeping the two bus bar disconnectors are closed as a preference condition and check which BB zone shall operate.

13. Repeat the above steps for all phases.

14. Normalize all CT circuits after the completion of the sensitivity test.

15. Repeat the test for all feeders (holding one feeder as a reference for each test)



TCSP105R01/TMA


5.14 Stuck Breaker Protection Stability & Sensitivity Test

(Reference SEC central specification 15/1/5) The stuck breaker protection scheme uses inverse definite minimum time (IDMT) over current relays energized with the sum of current being supplied into the bus-bar from associated bus-sections & transformer incoming circuits. Purpose of this test is to verify the proper application of stuck breaker protection including, CT polarity, CT summation secondary wiring circuit, CT selected secondary ratio, final setting of the relay with respect to primary current, and selective tripping arrangement of the circuit breakers associated with this scheme.


ITEM DESCRIPTION REMARKS 1. General Visual Inspection. As per 4.1

2. The CT loop test, CT primary Injection & Single earthing point checked activities should be completed before start the stuck breaker stability & sensitivity test.

3. Verify that CT ratios for all CT’s used in the current summation scheme are matching for proper operation of the relay.

4. Check for proper shorting facility after the summation point of all CT’s Or as required by specification

5. Check that the acceptance test and final setting for this relay have already been completed with satisfactory results. Check that all CT's were tested.

6. Check that all associated CT cores are having the same Knee point nearly.

7. Check the time grading of operation between the feeder O/C+E/F relays, the stuck breaker protection, and the transformer incomer LV O/C +E/F relays.

8. Verify proper application of single earthing point in relay panel


1. General Function Tests. As per 5.1

2. Caution: Check that any high impedance protection (ex. Transformer REF protection) is shorted before primary injection on their CT Cores.

3. Caution: Any CT cores not related to stuck breaker protection should be shorted for safety.

4. All associated circuit breakers should be closed in service position.

5. You may have to test each protection element (O/C or E/F) independently depending on the setup of primary injection.

6. Stability through simulation of external fault: Starting with a small primary current (5%of rated current). Inject primary current on the Bus-bar through a path energizing two of



TCSP105R01/TMA



the CT’s used in the stuck breaker scheme and simulating an external fault. Verify with a clamp ammeter or a phase angle meter that the CT secondary currents are correct depending on CT ratio. Verify with a clamp ammeter that the summation current of both CT secondary circuits is 0mA. Verify the reading on the relay for 0A primary current. Increase the current injection gradually until you exceed the setting of the relay, the relay should not operate and the current summation readings shall remain 0mA. Repeat the stability test for other phases Using once of the CT’s used in the previous test as a reference, repeat the stability test for other CT’s by changing the path of primary injection to energize those CT’s and taking the stability measurements to verify the CT polarity, secondary ratio and secondary wiring is correct.

7.

Sensitivity test through simulation of internal fault: Choosing one CT as a reference (incomer or bus-section), reverse the polarity of the other CT (bus-section or incomer respectively), using external jumpers of suitable current rating and the isolating facility of the short-isolate terminal block for that CT. Starting with a small primary current < 50A. Inject primary current on the Bus-bar through a path energizing two of the CT’s used in the stuck breaker scheme and simulating an external fault. Verify with a clamp ammeter or a phase angle meter that the CT secondary currents are correct depending on CT ratio. Verify with a clamp ammeter that the summation current of both CT secondary circuits is double the secondary current of each individual CT and that the summation is correct. Verify the reading on the relay for 100A primary current (or double the injected primary current). Increase the current injection gradually until you exceed 50% of the setting of the relay, summation readings shall increase gradually until the relay picks up. Once the relay picks up, stop increasing the primary injection and record the exact pickup current of the relay in primary and secondary currents. After the preset time delay the relay should operate. Ensure the operation of all trip / lockout relays. Ensure the tripping of all associated circuit breakers. Ensure the proper initiation of panel indication or alarms as per the scheme. Repeat the sensitivity test for other phases Using once of the CT’s used in the previous test as a reference, repeat the sensitivity test for other CT’s by changing the path of primary injection to energize those CT’s and taking the stability measurements to verify the CT polarity, secondary ratio and secondary wiring is correct.


9. Make sure that any protection elements that were disabled during the test



TCSP105R01/TMA



have been brought back into service (Earth fault).

10. Ensure that all shorted CT’s cores are normalized.

11. Ensure that all shorted high impedance protections such as transformer REF are normalized.

Example primary injection setup:

GT2

Feeder

Incomer B

PRIMARY INJECTION

DEVICE

SEC A/B

51/ 51N

A: Ammeter for measuring primary current mA: Ammeter for measuring Summation current

SEC B/C

86SB

A

mA



TCSP105R01/TMA


5.15 Transformer Differential Protection Stability & Sensitivity Test



5.15.2 Electrical Checks


1. CT loop and primary injection tests should be completed for High voltage and Low voltage sides.

2. Make sure there is no more than one earthing point on the CT at the secondary circuit for HV side and LV sides.

As per the approved logic diagram.

3. The final settings must be applied and tested before the stability test.

4. Check that all associated CT cores are having the same Knee point nearly for high voltage side and low voltage sides for high impedance protection.


6. Caution: Any CT cores not related to the transformer protection should be shorted for safety.

7. Check that Transformer is short-circuited at the LV side after the transformer LV Side CT for differential protection.

See illustration below

8. Isolate the Differential Protection Trip Links

9.

Before the test & switch on the 3 phase power supply: Check the balance and phase sequence of the three phases power supply at the HV side of the transformer. Switch on the power supply and check phase sequence and voltage values.

10.

Measure primary current of transformer HV &LV sides and compare with the expected calculated values. The phase angle between primary and secondary current for each phase depending on the transformer vector group.

11.

Stability: Measure (Primary current – secondary current – phase angles) for HV and low LV side. Read the differential operating and restrain Currents, the differential should be 0A

12.

Sensitivity: Reverse the polarity of CT for any side (HV or LV), by reversing that CT secondary wire. Measure and read primary, secondary, differential operating and restrain currents and phase angles. If the differential current is high enough, check the relay indication for pickup and trip.

13. Normalize the reversed CT and repeat the test for other phases. 14. Normalize the trip isolation links. 15. Normalize the shorted CT cores.



TCSP105R01/TMA




TCSP105R01/TMA


5.16 Restricted Earth Fault Protection Stability & Sensitivity Test

- It is known that the restricted earth fault protection aims to protect the star windings (primary or secondary windings or both) of the power transformers used in transmission networks and this type of relay is used to protect the transformer windings against internal earth faults. - As shown, the protective circuit consists of 4 CTS (a CT for each phase and one for the neutral point); the four CT's are connected in parallel with the REF relay as in the figure.


ITEM DESCRIPTION REMARKS 1. Check the correct terminal connections.



4. IMPORTANT: Remove the neutral earthing resistor (NER) bypassing

it to increase the current to facilitate measuring.

5.

Holding the neutral CT4 as a reference: Apply single phase voltage on each phase (Red, Yellow, and Blue) individually. Stability:

Measure secondary current and its angle for the phase CT and neutral CT and check the values to decide the stability. Check the differential current and verify that it is zero. Measure the voltage across REF terminals and it is must be approximately 0 V.

6. If the relay operates wrongly in the previous case, ensure that there is no saturation in any of the CT's or any wrong circuit connection, or different CT ratios.

7.

Sensitivity: Caution: REF is a high impedance protection and should be tested as a trip/no trip test with short durations of power supply switching ON to protect the relay from burning. Isolate the trip link for REF protection. Cross the wiring for the phase CT (holding the neutral CT connection as a reference) Measure secondary current and its angle for the phase CT and neutral CT Check the differential current and verify that it is the summation of the two secondary currents. Check the REF terminal voltage with a voltmeter. If the measured voltage is greater than the final setting, normalize the trip link and observe the breaker tripping.

8. Repeat the test for the other phases (Yellow, Blue) 9. Normalize the CT connections. 10. Normalize trip isolation links


TCSP105R01/TMA




5.17 End To End Test for Over Head Line Feeders

5.17.1 Distance Protection

ITEM DESCRIPTION Remarks

The following activities should be completed before start the end to end test

a. Secondary injection for main relays (Distance, Directional Earth Fault, and Over-Current).

b. Final Settings Applied for the main relays. c. Function Tests for Relay and Control Panels (for proper command

and indications). 1.

d. Function Tests in GIS (for proper operation of the breaker) e. Fault & Event Recorders commissioned and properly interfaced. f. Proper Operation of Bus-bar Protection and Circuit Breaker Fail

schemes g. Communication system tests.

Simulate all the commands (trip, block, communication failure, auto re-close…etc) that will be sent to the remote end from the output contacts of your protection and control relays as per the scheme provided:

2.

Check functions and alarms of each communication channels individually by simulation these functions alarms in communication panel and check functions and alarms in remote end communication panel

Check segregation between functions and alarms and channels. The communication channels with smallest prolonging time value are used for distance communication scheme and another for inter-tripping send and receive.

3.

POTT ( permissive over reach transfer trip) This is accomplished by secondary injection on your Distance relay.

a. Simulate z1 fault and measure time of Z1 trip output contact and check output of carrier send signal is obtained and check indication and alarm output contact.

b. Check the other zones operate without carrier send signal. c. Simulate carrier receive and check that the relay trip only during z1

with its time and check tripping during extended zone with extended zone time plus receiving communication time.

If it is applied in the final setting

d. Check if extended zone fault without CR, trip with Z2 time and CS to the remote end.

4.

e. Check if all zones except extended zone the relay tripping results without release from the opposite line end (carrier receive), allowing the protection to function with the usual grading characteristic independent of signal transmission.

f. Check that the POTT is for forward direction only. g. Check all indications and alarm output contacts. h. Check communication fail condition according to the relay logic

scheme tripping with basic scheme.



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5.

PUTT ( permissive under reach transfer trip) a. Simulate Z1 fault and measure time of Z1 trip output contact and

check output of carrier send signal CS is obtained and check indication and alarm output contacts.

b. Check that only Z1 transmit CS and the other zones and extension zone operate without carrier send signal.

c. Check if extended zone fault with CR , trip with extended zone time plus receiving communication time and without


6.

Blocking scheme a. Check if the forward zones fault without blocking signal receives

from remote end, aided trip with aided trip time and no CS to remote end.

b. Check if the forward zones fault with blocking signal receives from remote end, trip with zones delay time according to final setting and no CS to remote end.

c. Check if the reverse zone fault, trip with reverse zone time and CS to remote end.

d. Check if communication channels fail the relay operates with basic scheme.


7.

Week in feed function a. echo only

i. Check if C.B off & carrier receive the Echo signal send immediately.

ii. Check if C.B. on & carrier receive the Echo signal send after time delay (according to setting).

b. echo and trip i. Check if C.B off & carrier receive the Echo signal send

immediately without local trip. ii. Check if C.B. on & carrier receive local trip and Echo signal

send after time delay (according to setting).


8.

If we have two parallel lines, so we have two Telec. Devices ( 4 channel for each device ) We can say : Device one – D1 , Device two – D2 For testing the CBF : D1 and D2 are Healthy Step-1: CBF For Line-1 operates and send two command in the same time

( DTT-1 through D1 ; ch-2 & DTT-2 through D2 ; ch-2 ) ( CB Trip )

Step-2: CBF For Line-2 operates and send two command in the same time ( DTT-1 through D2 ; ch-3 & DTT-2 through D1 ; ch-3 ) ( CB Trip )

Step-3: CBF For Line-1 operates and send only one command DTT-1 or DTT-2 ( No Trip )


For testing the CBF : one device is Healthy and the other is Faulty Step-5: CBF For Line-1 operates and send ( DTT-1 through D1 ; ch-4 &

D2 is failed ) ( Trip )




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Step-6: CBF For Line-1 operates and send ( D1 is failed & DTT-2 through D2 ; ch-4 ) ( Trip )

Step-7: CBF For Line-2 operates and send ( DTT-1 through D2 ; ch-4 & D1 is failed ) ( Trip )

Step-8: CBF For Line-2 operates and send ( D2 is failed & DTT-2 through D1 ; ch-4 ) ( Trip )

9.

For each of the previous conditions, check Auto-recloser Initiation:- a. Check auto-recloser initiation from fast tripping relay by simulation

of instantaneous protections. b. Check auto-recloser initiation from intertrip receive relay and Check

in remote end fast instantaneous protections operate which send that intertrip signal.

c. Check auto-recloser blocking initiation from delay or backup protection tripping relay by simulation of delay or backup Protection.

d. Check auto-recloser blocking initiation from intertrip receive relay and check in remote end delay or back up protection operate which send that intertrip signal.

Depending on the approved scheme if applicable.

10.

For each of the previous conditions, check that Carrier Send and Received events are recorded at the Fault or Event recorder for signals initiated from the remote end.

Depending on the approved scheme if applicable.

11. Repeat the previous tests at remote end

12. Simulate communication channel failed, and check the operation of the relay on basic scheme.

5.17.2 Directional Earth Fault Protection


1.

Following activity should be completed before start the end to end test a. Secondary injection for main relays (Distance, Directional Earth

Fault, and Over-Current). b. Final Settings Applied for the main relays. c. Function Tests for Relay and Control Panels (for proper command

and indications). d. Function Tests in GIS (for proper operation of the breaker) e. Fault & Event Recorders commissioned and properly interfaced. f. Proper Operation of Bus-bar Protection and Circuit Breaker Fail

schemes g. Communication equipment and communication channel is

commissioned and in service.

2. Simulate all the commands (trip, block, communication failure, auto re-close…etc) that will be sent to the remote end from the output contacts of your protection and control relays as per the scheme provided:

3. Check functions and alarms of each communication channels individually by simulation these functions alarms in communication panel and check functions and alarms in remote end communication



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panel. Check segregation between functions and alarms and channels. The communication channels with smallest prolonging time value are used for directional earth fault communication scheme and another for inter-tripping send and receive.

4. BLOCKING SCHEME:

Directional blocking scheme

a. Forward Fault: i. Simulate a forward fault and check there is no initiation of CS

to remote end and no CR received. (Be sure the communication channels are healthy).

ii. Check tripping instantaneously at setting value.(aided trip) iii. Check inter-trip send and receive and which tripping relay

initiate send relay. iv. Repeat the previous steps from remote end Check that Trip

Signal should appear. Measure the operating time, use Trip signal from the configured binary output to stop the timer, compare the measured time with the set value of Coordination time in the two ends.

b. Reverse Fault:

i. Simulate a reverse fault and check there is a CS in local end and CR in the remote end.

ii. Check there is no tripping in the remote end relay. iii. Check the tripping occurred at reverse delay setting time at local

end. iv. Starting again and simulate a forward fault in the remote end,

(and reverse in the local end). Check the CS in the local end and CR in the remote end and no tripping appear in the relay of the remote end.

Repeat the previous steps from remote end Check that Trip Signal should not appear.

If it is provided in approved schematic drawings, protection requirement and according to specification. , and if it is applied in final setting...

5. PERMISSIVE SCHEME:

Directional comparison scheme a. Check that the communication channels are healthy b. Forward Fault:

On the remote end, simulate a forward fault and check that the carrier send (on the remote end) is generated correctly and verify that the carrier is received locally. This CR will simulate a trip permission Signal reception (Permissive Signal). Simultaneously Simulate an earth Fault in line direction,

Check that Trip Signal should appear after set coordination time delay. Use the Trip Signal from the configured binary output to stop the

If it is provided in approved schematic drawings, protection requirement and according to specification, and if it is applied in


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timer, compare the measured time with the set value of Coordination time.

final setting.

c. Reverse Fault: On the remote end, simulate a reverse fault and check that NO carrier is sent and that no carrier is received locally.

Simulate an earth Fault in line direction and wait longer than the set value of Coordination time(Tcoord), Check that No Trip Signal should appear. Check that assigned binary output Contact for carrier Send (CS) should operate.

6. WEAK INFEED FUNCTION. If it is

provided in approved schematic drawings, protection requirement and according to specification, and if it is applied in final setting.

a. Echo only. Open the local Circuit Breaker and simulate a forward fault at the remote and check that a CR (Permissive Signal) is received correctly. Check locally that the DEFR sends (or Echo) a permissive Signal and that it is received correctly at the remote end.

b. Echo and trip. Close Local Circuit Breaker and simulate a forward fault at the remote

end. Verify that a CR is received locally (Permissive Signal), and apply residual voltage (DEF with Residual voltage level) with little or no current. Check that the relay will carry out a “Weak in-feed” trip and Send a Permissive Signal. (CS) to the remote end and allowing it to carry out a Carrier aided trip also.

Check in the fault recorder level of fault voltage, fault current, relay starts, relay trips indication and time.

7.

8. Repeat all the previous tests at the remote end. Simulate a communication failure condition and check the operation of the relays on the basic scheme.

9.


5.18 End To End Test for Under Ground Cable Feeders

5.18.1 Pilot Wire Cable Differential Protection

ITEM DESCRIPTION REMARKS Ensure that Pilot wire cores are matched between local station and remote station by colors, Continuity, Loop resistance and Insulation resistance.

1.

Adjust the pilot stabilizing resistors and final setting based on the actual measured pilot loop resistance.

2.

Check pilot supervision indications properly if fail or not, it must be correct (pilot open and pilot cross will give pilot open indication in supervision).

3.

Check pilot DC current is within the manufacturer recommended supervision current limits.

4.

(If you found current equal zero that means there is crossing in pilot wire). 5. Check supervision voltage send and receive for both substation

Using the pilot isolation terminal blocks, simulate pilot failure conditions: 6. Open circuit, short circuit, cross wired and make sure that the supervision

alarms are generated correctly. Inject current on the over-current starter element or simulate an over-current condition by energizing the start input of the line differential relay.

7.

Check the operating current (pilot relay current and main pilot current) in local and remote substations by current Injection for pilot relay.

8. Check the relay’s output voltage for the injected current. Increase the injected current until the remote breaker trips (While recording the sent and received pilot voltage). Check inter-trip scheme by Closing local CB then send inter-trip, remote CB will trip. During this, measure send voltage in local substation and measure receive voltage in remote substation and repeat for remote substation.

9.

10. Check operating time (loop time).

5.18.2 Fiber Optic Cable Differential Protection

ITEM DESCRIPTION REMARKS Ensure that fiber optics pairs are matched between local station and remote station and that the Optical Line System has been commissioned and is in service.

1.

Check fiber optics supervision indications for communication if fail or not, it must be correct.

2.

Make sure that the current readings are matching locally and remotely. 3. Increase the current injection and check the operation and tripping of the

relay in local and remote substations. ( for all phases) 4. Check alarms "inter-trip send and receive faulty" 5. Check supervision voltage send and receive for both substations.

Check inter-trip scheme by Closing local CB then send inter-trip, remote CB will trip. During this, measure send voltage in local substation and measure receive voltage in remote substation and repeat for remote substation.

6.

7. Check operating time (loop time).



5.19 SCADA POINT LIST CHECK

5.19.1 Commands Tests ITEM DESCRIPTION REMARKS

1. All function and operation tests in the SS must be done 2. Check the wirings of the SCADA Command from RTU. 3. Check the ferrule of Cables.

Initiate the Commands from the Control Centre and check the operation at equipments one by one.

4.

Confirm that the command from the control center and operation of the equipment same.

5.

6. Take the print of commands & events for record and match. Make sure that all conditions are tested with positive and negative test conditions.

7. Example of negative test: Selector switch is in local & a close command is received from Electrical control center does NOT close the circuit breaker.

5.19.2 SCADA Back Indication Tests

TEM DESCRIPTION REMARKS

1. All function and operation tests in the SS must be done 2. Check the wirings of the SCADA Back Indications from RTU. 3. Check the ferrules.

Initiate the Commands from the Control Centre and check the back indication at RTU and Control Centre.

4.

Confirm that the command and Back Indication of the equipment same. 5.

6. Take the print of commands & Back Indication and match.

5.19.3 SCADA Alarms Tests ITEM DESCRIPTION REMARKS

1. All function and operation tests in the SS must be done. 2. Check the wirings of the SCADA Alarm from RTU. 3. Check the ferrules.

Initiate the Alarms from the equipments and check the Alarms at RTU and Control Centre.

4.

Confirm that the Alarms initiated and at the RTU and Control Centre are same.

5.

Check the alarm label and group alarm label received at the control center are matching the approved point list.

6.

Make sure that the alarm types are correct (trip / non-trip or urgent / non-urgent).

7.

Make sure that alarm system failure alarm is received at the control center.

8.

Take the print from S.O.E. & at RTU and Control Centre and match. 9.



5.20 Metering and Readings through SCADA to ECC ITEM DESCRIPTION REMARKS

Study the schematic diagrams for metering and transducers generating signals for the SCADA.

1.

Supply the currents and voltages to the transducers by the secondary injections and take the readings from the Remote Terminal Unit of SCADA.

2.

3. Compare the inputs and the readings at Remote Control Unit. Check the readings of voltages up to two digits, currents up to three digits and frequency up to one digit after decimal point.

4.

Check the sums, maximum, minimum, averages values etc. at Remote Terminal Unit of SCADA.

5.

Inject current at the transducer inputs and make sure that the current readings are being received correctly at the control center.

6.



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5.21 Pre-Energization Confirmation Checks ITEM DESCRIPTION REMARKS

1.

ALL current circuits of all bays and equipments must be reviewed and checked. All current circuits and terminal blocks screws must be good tightened. The (short and isolate – single earth point – CT ratio) must be according to schematic drawing.

2. All test formats must be checked and signed by contractor and sec engineers.

3. All activities must be done and no Class A snags are remaining. 4. Final trip test activity test format must be checked.

5. All (closing, tripping, alarm, voltage, SCADA, communication, etc.) circuits terminal blocks screws must be good tightened.

6. All VT circuits MCB's closed, fuses in place. All voltage circuits in SS must be reviewed and terminal blocks screws must be good tightened.

7. All supplies to protection, control, switchgear, etc., are normal. 8. No abnormal relay targets, alarms, SCADA SOE indications.

9. All relays have approved settings applied and have been fully tested and are in service.

10. All alarm relay settings are finalized and the relays are locked.

11. Relays that have a backup battery for memory storage have their batteries installed and the temporary battery covers removed.

12. All relays Time and Date settings are correct and reviewed.

13. All snags must be classified and revised. All class A snags must be cleared.

14. All switchgear and other power equipments testing are completed.

15. All protection equipment is properly labeled. 16. All fire/smoke alarm systems are fully tested and in service.

17. All necessary fire fighting equipment is on site and accessible without obstruction.

18. Confirm all men and tools are clear of equipment to be energized and that all personnel are aware of the pending energization.



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5.22 During Energization Confirmation Checks


1.

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

2.

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 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. (remove one phase voltage to result summation of another two phases and make short circuit for another two current phases to obtain the third phase as a input current to the relay) according to obtained values of voltage, current and angle the relay action. Make reverse polarity and check the relay action.

e. For REF and bus differential relays, check to ensure minimal spill currents in service. Test the differential circuit by shorting 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 at 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



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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.

3.

After two transformers have been successfully energized, perform a back to back test to check differential protection measurements are ok. Parallel the two energized transformers. Switch the tap changers to manual operation and manually raise or lower one of the two transformers from nominal tap to create a voltage difference and circulating current. Check the current readings in the CT secondary circuits. Check that all protection relays are working properly.

4. After the substation is properly loaded, check parallel operation and master / follower scheme for automatic voltage regulation relays.



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5.23 On Load tests

5.23.1 On Load tests for CT/VT Circuits & Transformer Inspection. ITEM DESCRIPTION REMARKS

1. Visually inspect CT compartments in the GIS, Switchgear, etc... and make sure there is no abnormal sound.

2. Visually inspect the Power Transformer & Auxiliary Transformers and make sure there is no abnormal sound.

3. Make your own measurements of the secondary current for all phases and in neutral with Clamp meter in metering and protection cores, the values should be in accordance with the ratios of the cores.

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

5. For protection devices with built in metering functions check current, voltage magnitudes, and phase angles, real and reactive power.

6. Check the direction of power, active component and reactive components (power in line direction is positive) and check power factor

7. For VT Circuit check Secondary Voltage between phases and the neutral with volt meter which should be in accordance to the VT ratio.

8. Check phase rotation with a phase rotation meter connected across the three phases.

5.23.2 On Load Line/Cable Differential Protection Stability & Sensitivity


1. Ensure that the new Feeder was energized without any load for one hour at least before on load Test.

2. Ensure to decrease the tripping time of over current protection to less than 0.5 sec (if DMT O\C).

3. Ensure that the tripping of Line or Cable differential Relay is ISOLATED to prevent false operation of relay.

4. For relays that rely on fiber communication to send inter-trip signals, Isolate tripping facility on both sides of the line (local and remote end) to prevent accidental disconnection of the power circuit.

5. If necessary, isolate any relay operated alarm contacts and any breaker failure initiation contacts as per the scheme

6. Ensure that the Feeder is loaded by 25% at least from its rated current.

7. Read phases currents, they must be balanced and measure the differential current must be close to zero in stable case.

8.

Check the relay performance (Trip Action) at unstable condition by reversing the current direction by one of the following methods : Reverse the current direction from relay software. Reverse two Current phases by reversing current wire (must prevent opening of CT circuit by making short circuit for current pass). By shorting one current phase with neutral to make current unbalance

9. If the differential current is lower than the relay setting, reduce the setting of the relay to observe its operation.



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ITEM DESCRIPTION REMARKS 10. Normalize the relay setting

11. Normalize the CT circuit (Shorted or cross wired) or the software internal current direction.

12. Reset the relay to make sure that any operated trip / alarm / CBF start contacts (latching or non-latching) have normalized

13. Normalize the isolated trip links and any isolated contacts (alarm, breaker fail …etc)

14. Ensure that the tripping time of over current protection as final setting after finished the test (if DMT O/C).

5.23.3 On Load Confirmation of Relay Directionality

(Distance / Directional Over-Current and directional Earth Fault protections) ITEM DESCRIPTION REMARKS

1. Use test plug to isolate tripping circuit and take all precautions to prevent any current circuit opening by using good type of jumper wires for shorting CT plug current terminals.


3. Isolate any relay operated alarm contacts and any breaker failure initiation contacts as per the scheme

4. Ensure that VT fail function of directional Relay is switched off to prevent relay block.

5. Ensure that the Feeder is loaded by 25% rated current at least.

6. Ensure to decrease the tripping time of over current protection to less than 0.5 sec (if DMT O/C).

7. Measure the currents magnitude with phase angles and confirm that angle measured is approximately same as on power meter of this circuit and measurements with system control.

8. Compare the measured values of phase angles at local end with the ones measured at remote end. Results at both ends should be approximately 180 degrees out of phase.

9. For numerical relays, direction can be verified from relay on load measurements by relay as explained in respective relay manuals.

10. Check the Power direction by checking the current direction, if the feeder export in this case the active power will be forward (+ve), and Vice versa the power will be reverse (–ve)

11.

For export feeder : (Active power is +ve, and reactive power is +ve for Lagging and –ve for Leading Power factor.) a. Remove one red phase voltage, ensure that the distance protection will

pickup and trip for a forward fault (Z1, Z2 … etc) b. Ensure that the directional O/C protection picks up and trip for that

forward direction. Swap polarity of the phase current R and protection will not operate.



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c. If the distance protection picks up or trips for a reverse fault (Z3’, Z4, Z5, Zreverse) …etc then the directionality is incorrect.

d. If the directional over current protection not operate check setting values and decrease until operate or check directionality.

For import feeder: (active power is –ve, and reactive power is -ve) for Lagging and +ve reactive power for Leading Power factor.) e. Remove one phase red voltage, ensure that the distance protection will

pickup and trip for a reverse fault (Z3’, Z4, Z5, Zreverse …etc) f. Ensure that the directional O/C protection will not operate for that

reverse direction. Swap the polarity of current phase R and ensure that protection will operate at setting decreased to load current.

If the distance protection picks up or trips for a forward fault (Z1, Z2) …etc then the directionality is incorrect.

For directional earth fault: (remove one phase voltage to result summation of another two phases and make short circuit for another two current phases to obtain the third phase as an input current to the relay) according to obtained values of voltage, current and angle the relay action. Make reverse polarity and check the relay action.

12. Repeat the previous procedure for Yellow and Blue voltage phases, and check relay performance.

13. Reset the relay to make sure that any operated trip / alarm / CBF start contacts (latching or non-latching) have normalized

14. Normalize the isolated trip links and any isolated contacts (alarm, breaker fail …etc)

15. Ensure that all hardware connections are normalized ok as per drawing and tightness.

16. Ensure that the tripping of Directional relay is in services after finished the test.

17. Ensure that the tripping time of over current protection as final setting after finished the test (if DMT O/C).

5.23.4 Transformer Differential Protection on Load Stability Tests


1. This test should only be performed after the transformer has been energized for at least 24 hours with no load, and all temperature readings and indications are healthy.

2. To load a transformer, start with approximately 10% rated current. And check operating current in differential relay, so the loading should be gradually and checking operating and restraint currents of the relay.

3. Check the phase angle between primary and secondary current for each phase depending on the transformer vector group.

4. Check the readings of Primary, Secondary and differential Currents (spill currents between phases)


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If deviation in expected values of operating and restraint current for all phases then isolate the differential relay tripping circuit and solve the problem in current circuit or in relay setting.

5.

5.23.5 Restricted Earth Fault Protection on Load Stability Tests


This test should only be performed after the transformer has been energized for at least 24 hours with no load, and all temperature readings and indications are healthy.

1.

Ensure that the transformer is loaded by 25% at least from its rated current. 2. By mean of clamp meter, check the current balance of all phases or read the current and angles of phases if the relay is digital.

3.

For high impedance REF, by using mean of volt meter, ensure that the voltage across relay coil terminal almost equal to zero which related to differential current.

4.

5.23.6 Bus Bar Protection on Load Stability Tests


1. With the bus-bar loaded with at least 25% of the rated current: Measure the current and angle of all current circuits in all bays and in BBP panels for discrimination and check zones. Check stable current Is and differential current Id values in the discrimination zones and check zone. Differential current Id should be zero

2.

5.23.7 Stuck Breaker Protection On-Load Stability & Sensitivity Tests

Purpose of this test is to verify on-load the proper application of stuck breaker protection including, CT polarity, CT summation secondary wiring circuit, CT selected secondary ratio.


Stability on-load: With at least 25% load on the circuit: Verify with a clip on meter or a phase angle meter that the CT secondary currents are correct depending on CT ratio for incomer and bus section breaker CT’s.

1. Verify with clip on meter that the summation current of both CT secondary circuits is matching to the summation of load of the bus section. Verify the reading on the relay in secondary and primary current to equal the summation of load for that bus section. Repeat the stability readings for all phases (R, Y, and B).


5.24 Recommended Test Equipment

Type of Test Recommended Equipment Description


GE – Programma - Freja 300 with 3 digit resolution

Secondary Injection – low burden

Integrated relay test bench for current, voltage and frequency tests with built in binary inputs and outputs and built in timer.

Omicron CMC series

Secondary Injection – high burden

GE – Programma - Sverker 750 Integrated relay test bench for current & voltage tests with built in binary inputs and built in timer.

Primary Injection – low burden

Omicron – CPC series Primary injection tester capable of injection up to 200A continuous current and up to 300A for 15minutes.

Primary Injection – high burden

GE - Programma – Oden A Primary injection tester capable of injection up to 1000A continuous current.

CT Tests (polarity, ratio, winding resistance, magnetization curve)

Omicron – CT Analyzer Integrated CT tester: capable of completing all CT tests within 3 minutes and features accurate calculation of CT Error ratio by applying varying burden during testing.

Omicron – CPC series

Insulation Resistance Megger – BM11D Insulation resistance tester with up to 5kV applied voltage and with a built in timer

Stability & Sensitivity tests

Zero Phase Angle Meter

On-load directionality tests Numerical relays Omicron CMC series

GE – Programma – Freja 300 with laptop and software

Auxiliary relays -- Suitable wattage variable resistor (up to 2A) for testing relays from a stable substation DC DB.



6.0 SUBSTATION AUTOMATION SYSTEM (SAS)

6.1 The contractor shall submit the test procedure for SAS equipments, devices and relays 6 months prior to start pre-commissioning for approval. These tests shall be based on IEC 61850 Substation Automation System (SAS).


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7.0 Substation Noise levels Measurement.

7.1 The Contractor shall submit the procedure, arrangement and schedule for noise levels measurement at the substation for approval according to the following scenario.


Measurement of average background noise levels at substation site after the mechanical completion of the project during day time and night time prior to energization of Substation Transformers.

1.

Measurement of average Transformers noise level at ONAN rating at the site for comparison with the value measured in the factory and declared by the transformer manufacturer. (Note: the expected measured average noise level value is equal to measured transformer noise level carried out at transformer factory per IEC 60076-10 + the actual average background noise level measured at substation site as stated in point no.1).

2.

Measurement of Noise levels at substation boundaries. The result of noise levels measured at boundaries shall not exceed the value specified in TES-P-119.02, Rev.0, clause 5.2.6 of 65dB (A) during day time between (06:00 – 22:00hrs.) and 55dB (A) during nigh time between (22:00 -06:00hrs.)

3.

TCS-P-105 Revision No. 01


PRE-COMMISSIONING TESTS/PROCEDURES

FOR SEC TRANSMISSION ELECTRICAL INSTALLATIONS

ATTACHMENT # 15 (CHECK LIST)


ATTACHMENT # 15 CHECK LIST


S/S Name / No:………….. Bay No.: ………………….

INDEX INTRODUCTION 5 1.0 CHECK LIST OF PROCEDURE FOR TESTING OF MAIN EQUIPMENT 5

1.1 Oil Filled Power Transformer 7 1.2 Shunt Reactors 11 1.3 Bushings Inspection and Testing 14 1.4 Surge Arrestors 15 1.5 Station Service Transformers (less than 2 MVA) 16 1.6 Neutral Earthing Resistors. 18 1.7 Current Transformers 19 1.8 Potential Transformers 21 1.9 Capacitive Voltage Transformers 23 1.10 Coupling Capacitor Voltage Transformer 24 1.11 HYBRID/GAS INSULATED SWITCHGEAR (GIS) 25 1.12 Metal Clad Switchgear 29 1.13 Metal Enclosed Bus Duct 32 1.14 Indoor and Outdoor Bus Structures 33 1.15 Indoor Circuit Breakers 34 1.16 Outdoor Circuit Breakers 37 1.17 Disconnect & Grounding Switches 40 1.18 Circuit Switchers 42 1.19 LV AC/DC LV AC/DC Board and Circuit Breakers (380/220/127V) 43 1.20 230kV and 380kV XLPE Cables 44 1.21 230 kV and 380kV LPOF Cables 46 1.22 110kV and 115kV and 132kV XLPE cables 48 1.23 110kV and 115kV and 132kV LPOF Cables 50 1.24 69 kV XLPE power Cables 52 1.25 13.8 kV and 33 kV XLPE Power Cables 54 1.26 LV Cables 55 1.27 Control Cable 56 1.28 Pilot Cables 57 1.29 Overhead Lines 59 1.30 Protection and Control Panels. 62 1.31 Station Batteries 73 1.32 Battery Charger 75 1.33 AC Distribution Panels 76 1.34 DC Distribution Panels 77 1.35 LV AC Auto-Transfer Schemes/Switches 78 1.36 GROUNDING SYSTEM 79 1.37 Switchgear Air Compressor Systems 80 1.38 HVAC Systems 81 1.39 Dry Type Transformer 84 1.40 Ring Main Unit (RMU) 85 1.41 CAPACITORS BANK TEST 86 1.42 CAPACITOR AND ASSOCIATED REACTOR (REACTOR TEST) 87 1.43 Static VAR Compensation System 88

2.0 CHECK LIST OF PROCEDURE FOR TESTING PROTECTION RELAYS 97 2.1 General Mechanical Checks & Visual Inspection 98 2.2 General Electrical Tests 99




Check list S/S Name/ No.: …………………… Bay No.: ……………..


2.3 Guidelines for Testing Digital& numerical Protection & control Relays and IED’s 100 2.4 Auxiliary Relays 103 2.5 Timers (62) 105 2.6 Over/Under-Voltage Supervision Relays (59/27) 106 2.7 Compensation Voltage Protection -59ND 107 2.8 Trip Circuit Supervision 108 2.9 Definite Time Over-Current & earth fault protection relay 111 2.10 Inverse Definite Minimum Time (IDMT) Over-Current & earth fault protection

relay 112


3.0 CHECK LIST OF PROCEDURE FOR SCHEME AND FUNCTIONAL CHECKS 141 3.1 General Panel Function Tests 142 3.2 Local Control Cubicle (LCC) Panel Function Test 144 3.3 Relay & Control Panel Function Test 146 3.4 Transformer Function Test 151 3.5 Automatic Voltage Control Panel Function Test 153 3.6 Load Shedding & Under Frequency Panel Function Test 154 3.7 Bus Bar Protection Panel Function Test 155 3.8 ACSE / ABTS / TOP Function Test 156 3.9 ACCS – Automatic Capacitor Control System 157 3.10 Common Alarms Panel Function Test and Alarm Scheme Test 159 3.11 Final Trip Test 160 3.12 Synchronizing Relay 161 3.13 Bus Bar Protection Stability & Sensitivity Test 163 3.14 Stuck Breaker Protection Stability & Sensitivity Test 165 3.15 Transformer Differential Protection Stability & Sensitivity Test 168 3.16 Restricted Earth Fault Protection Stability & Sensitivity Test 170 3.17 End To End Test for Over Head Line Feeders 171 3.18 End To End Test for Under Ground Cable Feeders 176 3.19 SCADA Point List checking 178 3.19.1 SCADA Commands Tests 178

PART II: MECHANICAL CHECKS, VISUAL INSPECTIONS & ELECTRICAL TESTS Check list S/S Name/ No.: …………………… Bay No.: ……………..



3.19.2 SCADA Back Indication Tests 178 3.19.3 SCADA Alarms Tests 178

3.20 Metering and Readings through SCADA to ECC 179 3.21 Pre-Energization Confirmation Checks 180 3.22 During Energization Confirmation Checks 181 3.23 On Load Tests 183

3.23.1 On Load tests for CT/VT Circuits & Transformer Inspection. 183 3.23.2 On Load Line/Cable Differential Protection Stability & Sensitivity 183 3.23.3 On Load Confirmation of Relay Directionality 184 3.23.4 Transformer Differential Protection on Load Stability Tests 186

3.23.5 Restricted Earth Fault Protection on Load Stability Tests 186 3.23.6 Bus Bar Protection on Load Stability Tests 186 3.23.7 Stuck Breaker Protection On-Load Stability & Sensitivity Tests 187

4.0 CHECK LIST OF SUBSTATION AUTOMATION SYSTEM (SAS) 188 5.0 CHECK LIST OF SUBSTATION NOISE LEVELS MEASUREMENT 189



S/S Name / No:………….. Bay No.: ………………….

CHECK LIST INTRODUCTION

The check list is intended to provide information to commissioning engineers / Technicians who are assigned to inspect the contractor work and witness and commissioning testing on behalf of SEC to verify that the substation and transmission line equipments and system are acceptable as per SEC – Standard and specifications. The listing of commissioning checks and tests are based on SEC – Commissioning standards. (Attachment No. 15)

CHECK LIST OF PROCEDURE FOR TESTING OF MAIN EQUIPMENTS

1.0 CHECK LIST OF PROCEDURE FOR TESTING OF MAIN EQUIPMENT 5

1.1 Oil Filled Power Transformer 7 1.2 Shunt Reactors 11 1.3 Bushings Inspection and Testing 14 1.4 Surge Arrestors 15 1.5 Station Service Transformers (less than 2 MVA) 16 1.6 Neutral Earthing Resistors. 18 1.7 Current Transformers 19 1.8 Potential Transformers 21 1.9 Capacitive Voltage Transformers 23 1.10 Coupling Capacitor Voltage Transformer 24 1.11 HYBRID/GAS INSULATED SWITCHGEAR (GIS) 25 1.12 Metal Clad Switchgear 29 1.13 Metal Enclosed Bus Duct 32 1.14 Indoor and Outdoor Bus Structures 33 1.15 Indoor Circuit Breakers 34 1.16 Outdoor Circuit Breakers 37 1.17 Disconnect & Grounding Switches 40 1.18 Circuit Switchers 42 1.19 LV AC/DC LV AC/DC Board and Circuit Breakers (380/220/127V) 43 1.20 230kV and 380kV XLPE Cables 44 1.21 230 kV and 380kV LPOF Cables 46 1.22 110kV and 115kV and 132kV XLPE cables 48 1.23 110kV and 115kV and 132kV LPOF Cables 50 1.24 69 kV XLPE power Cables 52 1.25 13.8 kV and 33 kV XLPE Power Cables 54 1.26 LV Cables 55 1.27 Control Cable 56 1.28 Pilot Cables 57 1.29 Overhead Lines 59 1.30 Protection and Control Panels. 62 1.31 Station Batteries 73 1.32 Battery Charger 75 1.33 AC Distribution Panels 76 1.34 DC Distribution Panels 77 1.35 LV AC Auto-Transfer Schemes/Switches 78 1.36 GROUNDING SYSTEM 79 1.37 Switchgear Air Compressor Systems 80





1.38 HVAC Systems 81 1.39 Dry Type Transformer 84 1.40 Ring Main Unit (RMU) 85 1.41 CAPACITORS BANK TEST 86 1.42 CAPACITOR AND ASSOCIATED REACTOR (REACTOR TEST) 87 1.43 Static VAR Compensation System 88



S/S Name / No:………….. Bay No.: ………………….

1.1 Oil Filled Power Transformer

1.1.1 Mechanical check and Visual Inspection.

ITEM DESCRIPTION DONE REMARKS

1. Check the impact Recorder for any abnormal impact during Transportation.

2. Check all components are installed.

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

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

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

6. Check that all groundings are securely connected. (at least two grounding points to main tank are available)

7. Check that the piping to Buchholz relay has proper slop. 8. Check that the tank pressure is positive.( if applicable )

9. Check the valves between the tank and radiator (To be open).

10. Check the HV – LV and Tertiary (if applicable) bushing for any damage and completeness.

11. Check the color and quantity of silica gel in breather and oil pot level.

12. Check phase marking in cable box and it should match with GIS and cables.

13. Check all pipes – hoses and fan protection (not rubber or plastic).

14. Check the vertical – horizontal clearances of live parts to adjacent grounded point to conform standard.

15. Check integrity of diaphragm / air bag in the conservator. 16. Perform all of the manufacturer specific checks. 17. Check labeling of all auxiliary devices as per approved drawing.

18.

Check proper operation of all auxiliary devices as following: a. Tap changer ( upper – lower – out of step and interlock) b. Oil level gauges. c. Oil temperature gauges. d. Winding temperature gauge e. OLTC Oil / Gas surge (pressure) relay. f. Pressure relief device. g. Push buttons and indicators. h. Oil sampling port (main tank – OLTC). i. Upper and lower main tank valves. j. Tap changer diverter switch compartment, oil filtering

pumps and filter in good condition (if available). k. Buchholz relay. l. Check on line insulating oil dissolved gas and moisture

monitoring system (if applicable )







ITEM DESCRIPTION DONE REMARKS 20. Check that the oil sampling devices are reachable from ground level

21. Check oil level in main tank, conservator, tap changer tank and bushing etc.

22. Bleed trapped air at the bushing turrets and tank top.

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


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

26. Check that the temperature sensors oil well is two thirds filled with oil.

27. 33kV Load Break Switch Panel with HRC fuses for 33kV Station Transformer

28. Neutral Grounding Transformer or Reactor

29. Check that the each optical feed through unit is properly connected to the ports of Hot spot temperature measuring device

30. Internal inspection of the transformer before installation of the high side bushing of new transformer in order to inspect the upper yoke for any bents on the core and paint particles found.



1. Core Insulation Resistance at 1 kV DC.

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

3. Winding Resistance (DC) test ( at all taps ) (winding temperature shall be recorded, winding resistance shall be referred to 75°C)

4. Excitation Current measurements from primary side at each tap by applying 220 or 380 VAC on the HV terminal keeping the LV winding open.

5. Insulation power factor test for oil and bushing at 10 kV ac 6. Polarity, vector relationship and % Impedance test at normal tap

7.

Winding temperature indicator to be calibrated by heating the sensor in oil bath and check against standard thermometer. Also check by current injection, Check pick up/ Drop off of contacts:

- Fan, oil pump, alarm, trip contacts. Proper setting as per drawing to be applied and tested.

8. Oil temperature indicator to be calibrated by heating the sensor in oil bath and check against standard thermometer. Setting as per drawing to be applied and tested.

9. Percentage impedance (Short circuit impedance) test at lower tap, normal tap and higher tap

10. Turns Ratio ( all taps )





11. Check for current and voltage ratings of all motors for tap changer, oil filtering unit and fans match to SEC standard supply.

ITEM DESCRIPTION DONE REMARKS MCB’s for protection are set at proper over load settings

12. Fan motors current (starting, running, one phase removal and locked rotor) shall be measured and checked against rating .check if wiring size suitable to carry the current.

13. Check fan running direction to get air flow towards radiator and Phase sequence of supply voltage to fan motors circuits is correct.

14. MCBs in marshalling kiosk to be checked by current injection each pole for alarm and trip.

15.

On load Tap Changer checking check current and voltage ratings of tap changer motor a. Raise / Lower Control (Local – Remote) and indication. b. End of Tap Travel Control. c. End of winding travel control (both ends). d. Check that the windings are not open circuit during tap

changing. e. Check OLTC manual operation by hand crank f. Check insertion of hand crank automatically prevent electrical

motor drive operation. g. Check OLTC tap position indicator& operation counter h. OLTC motor load current to be measured for future reference

purposes i. Check all transmitters

16.

Bushing Current Transformer a. Polarity test b. Insulation Resistant test c. Secondary Winding Resistant (All windings and all taps). d. Current Ratio test e. Magnetization Characteristics (Minimum 5 points below and 2

points above the knee point. f. Verify secondary circuits, Terminals to Terminal. g. Burden Test. h. Demagnetize CT cores after all tests. i. Ensure that No open circuit at Secondary side.





17.

Functional Check of the following :- a. Liquid Level indicator (alarm/ trip) as applicable. b. Oil Temperature Device: Fans / pumps (stop, start alarm/ trip) c. Winding Temperature Device (alarm/ trip). d. Buchholz Relay (alarm/ trip). e. Oil / Gas Surge (pressure) relay (alarm/ trip). f. Pressure Relief Device (alarm/ trip). g. Rapid Pressure (Rise) Relay as per manufacturer testing

procedure (if applicable). h. On line insulating oil dissolved gas and moisture monitoring

system. i. Humidity/thermo meters for the heater of local panel are

at correct settings


18.

Insulation Oil Test :per 54-TMSS-01 Prior to energization, contractor should submit test report for insulation sample tested in an independent lab. For the following: : a. Dielectric strength

i) ASTM D877 ( 2.5mm Gap ) for unprocessed oil and for OLTC oil

ii) ASTM D1816 ( 1 mm gap )for oil in main tank

b. Neutralization Number ( ASTM D974 ) c. Interfacial Tension ( ASTM D971 ) d. Color ( ASTM D1500 ) e. Moisture Content (ASTM D1533 A) f. Power Factor Test ( ASTM D 924 ) g. Dissolved Gas in Oil Analysis (ASTM D3612) h. (Dielectric Dissipation Factor, Resistivity, Sediment

and / OR Perceptible Sludge). i. For transformer with Cellulosic insulating material,

perform sulfuric contents detection test as per ASTM D1275 method B. Another oil sample shall be given to SEC transmission for their own analysis and compression purpose

The oil sample should be taken by contractor using syringe from the oil valve.

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.

20. Frequency responses test if the transformer has been severely shocked during shipping. For all transformer frequency response and inrush current test.





21. Zero sequence impedance test


23. Magnetic balance test

24.

Oil dielectric test at site: Five samples shall be taken as following; top of main tank, bottom of main tank, OLTC tank, main tank conservator and OLTC conservator, the average result shall not be less than 50kV at 2.5 mm gap.




1.2 Shunt Reactors


ITEM DESCRIPTION DONE REMARKS 1. Check the impact recorder for any abnormal impact during

transportation.

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 micro-

switch. g. Push buttons and indicators. h. Oil sampling port (main tank). i. Upper and lower main tank valves.


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.





23. Bleed trapped air at the bushing turrets and radiators. ITEM DESCRIPTION DONE REMARKS 24. Check that the each optical feed through unit is properly connected to

the ports of Hot spot temperature measuring device




1. Core Insulation Resistance Test at 1 kV DC 2. Winding Insulation Resistance Measurement Test and Polarization

Index (P.I.) Test at 5 kV DC.

3. Winding Resistance Test. (winding temperature shall be recorded; winding resistance shall be referred to 75°C).

4. Inductance Measurement. 5. Impedance Measurement. 6. Winding temperature device to be calibrated 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 the sensor in oil bath and check against standard thermometer. Setting as per approved drawing to be applied and tested.

8. Insulation power factor test for oil and bushing 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. (alarm / trip) as applicable. d. Buchholz Relay (alarm and trip). e. Pressure Relief Device (alarm and trip) f. Humidity/thermo meters for the heater of local panel are at

correct settings.




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

Perceptible Sludge). i. Add Corrosive Sulfur test report

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.

13 Frequency responses test if the reactor has been severely shocked during shipping.




S/S Name / No:………….. Bay No.: ………………….

1.3 Bushings Inspection and Testing


1. Cleaning the insulator surface. 2. Check for tightness of all bolts for 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.


ATTACHMENT # 15 CHECK LIST S/S Name / No:…………..


Bay No.: ………………….

1.4 Surge Arrestors

1.4.1 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 securely connected. The Grounding Cable size should be checked.

5. Check name plate information for correctness as per SEC 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.





1.5 Station Service Transformers (less than 2 MVA)



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

2. Check for LV Side Air Circuit Breaker before cable at transformer side. If applicable.

3. Check for Danger Plate Warning installation. 4. Check earthing, color, painting, external damage, oil leakage, wheel

stopper, cable connection and bolt tightness, etc.

5. Check nameplate data against contract specifications. 6. Perform all special checks according to the manufacturer’s

instructions.

7. Check oil level in HV side cable box and its oil level indicator or HV fuses (if applicable).

8. Check that the off load tap-changer is set at the nominal voltage tap. 9. Check all devices are labeled correctly as per drawing.



1. Check LV side MCCB setting as per transformer current rating 2. Ratio Test (all taps), Insulation resistance measurement test on all

windings and polarization index (P.I.) test. test at 5kV DC

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). (Oil temperature shall be recorded;

winding resistance shall be referred to 75°C).

10. Back energization test at rated voltage for 15 minutes. 11. Perform functional tests of all auxiliary devices (as applicable ) 12 Oil dielectric test at site shall not be less than 50kV at 2.5 mm gap. 13. 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)

PART II: MECHANICAL CHECKS, VISUAL INSPECTIONS & ELECTRICAL TESTS Check list


S/S Name/ No.: …………………… Bay No.: ……………..


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. The oil sample should be taken by contractor.




1.6 Neutral Earthing Resistors.


1 Check nameplate data against contract specifications.

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

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

4 Test on NER HV side associated CT & power cable. 5 Inside visual inspection for any insulator broken. 6 Main circuits Resistance measurement test.

7 Insulation resistance measurement test. at 5kV DC >=1000meg

aohms

8 Cleaning of all internal as well as external to NER before energization.

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

10 Check that the enclosure earth terminal and resistor earth terminal are separate to allow the possibility of disconnection during testing.

11 Check the grounding resistance of the enclosure earth terminal and resistor earth terminal.

< 2 ohms




1.7 Current Transformers

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 according to SEC specification (ring type lugs).

8. Check CT locations physically and secondary terminal labeling has been done correctly.



1. Magnetizing current test 2. Winding resistance measurement. (Ambient temperature shall be

recorded; winding resistance shall be referred to 75°C).

3. Polarity test or flick test with battery. 4. Ratio test by current primary injection. 5. Insulation resistance test, as following:

a. Primary to ground 5kV DC for one minute. b. Primary to secondary 2.5kV DC for one minute. c. Secondary to ground and core to core 1kV DC for one minute.

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

primary injection of CTs. Installation of ct direction is as per the approved drawings and required weather proof labels are available, and check single point earth for each CT circuit.

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. In case of LV/MV switchgear The in/out movement of VT trolley is smooth and no excessive efforts are required.




11. Test inter-core coupling for all bus differential CTs. ITEM DESCRIPTION DONE REMARKS

12. NOTE: During stability test of power transformer, test all BCT's (bushing current transformers). That means primary injection test, turns ratio, check secondary circuits related to BCT by checking short & isolate facility, measure currents at each point of all loops and compare between measured values and expected values.

13. Note: It is necessary to demagnetize the cores before each test

ATTACHMENT # 15 CHECK LIST S/S Name / No:………….. Bay No.: ………………….


1.8 Potential Transformers



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.

7. Check integrity of primary fuses (if applicable). 8. Check insulation liquid level and leakage (if applicable). 9. Make sure that MCB for VT secondary is provided in the VT box. So

that the secondary cable up to LCC is protected

10. Gas leakage check for GIS VTs compartment



1. Winding Resistance Test. (Ambient temperature shall be recorded; winding resistance shall be referred to 75°C).

2. Insulation test as following: Primary to ground 5kV DC for one minute. Primary to secondary 2.5kV DC for one minute. Secondary to ground and core to core 1kV DC for one minute.

3. Ratio Test. 4. Polarity Test. 5. Primary and secondary fuses rating checks for (if applicable). 6. Ensure VT is included in switchgear and GIS high voltage test. 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. Capacitance and dielectric dissipation factor (tan ), this test apply only

to transformers with liquid immersed primary winding insulation for 110 kV and above





TABLE 1

SYSTEM

RATED

VOLTAGE

(KV)

RATED LOAD

FACTOR TEST VOLTAGE

(KV) FREQUENCY TIME PERIOD REMARKS

11 1.5 9.5 13.8 1.5 12

33/34.5 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

electromagnetic VT’s




1.9 Capacitive Voltage Transformers



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. Make sure that MCB for VT secondary is provided in the VT MK. So that the secondary cable up to LCC is protected

10. Check drain coils (if applicable). 1.9.2 Electrical Tests


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).



1.10 Coupling Capacitor Voltage Transformer

1.10.1 Mechanical Checks and Visual Inspections ITEM DESCRIPTION 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 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. Make sure that MCB for VT secondary is provided in the VT MK.

So that the secondary cable up to LCC is protected

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



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.





1.11 HYBRID/GAS INSULATED SWITCHGEAR (GIS)


ITEM Description DONE REMARKS1. 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 oC or lower.

15. Gas leaks 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 have definite mark scale.




ITEM Description DONE REMARKS18. Check the gauges are ambient Temperature compensated.

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

20. Check all wiring is colored according to approved drawings and specifications.

21. Verify that all front panel mounted devices (meters, push buttons, switches, indicator lamps, mimic buses, etc.) are installed as per drawings, fixed permanently and are correctly labeled.

22. Verify that all operating devices are correctly labeled.

23.

Perform mechanical checks and visual inspections on all component equipment: Circuit breakers. Current transformers. Voltage transformers. Disconnect and grounding switches.

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

25.

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


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 zone marking plates fixed over the gauges.

28. Check & confirm GIS VT’s primary isolation device with manual operation provided, along with it monitoring system locally as well as on mimic diagram in control room.

29. For hydraulic mechanisms the hydraulic system to be checked and assure that no leakage.


31. Check & confirm there are no any sharp edges for the cable trays or other metallic parts.

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


ITEM Description DONE Remarks

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





ITEM Description DONE Remarks 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 (CB’s, disconnect, etc.) in a closed position.

6. Check contact resistance separate test for CB and all DS.& ES

7. Functional check of all alarms, interlocking and indication circuits from the GIS to the local control cubicle.

8. CB’s, DS’s and ES’s Timing Test (Open & Close) with contact travel and speed analysis.

9. 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.

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

11.

GIS PTs to be included during AC HV tests on GIS when test frequency is well above rated Frequency, otherwise test at 1.5Un – one minute at rated frequency without secondary load. PTs secondary out put volts shall be measured accordingly during the high voltage test.

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

injection in each pole.

13. Measure current drawn by motor for CB and DS and check the results according to design.

14. Check VT HV neutrals externally available especially in case of VTS installed directly on cable feeder.


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

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

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




ITEM Description DONE Remarks Circuit breakers. Current transformers Voltage transformers Disconnect and grounding switches.

19. Functional test of trip free and anti pump circuits

20. Check Minimum control voltage trip (60%) and close (80%) operations.






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




1.12 Metal Clad Switchgear

1.12.1 Mechanical Check And Visual Inspection

ITEM Description DONE Remarks 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 of dust accumulation.

10. Check main and riser buses for correct phasing connections.

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 check and visual inspection on all circuit breakers.

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

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

15. Perform mechanical check and visual inspection on all disconnected 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.

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.




ITEM Description DONE Remarks 24. Check all wiring is correct according to approved drawings.

25. Check that all phase marking have been installed per specifications.


27. Check that all special tools, devices, etc., as per specification have been provided.

28. Check existence of warning signs according to SEC specification



1. Insulation resistance test of all wiring, cabling and auxiliary circuit in the panels.

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. Perform with 100 ampere DC by micro-ohmmeter from panel to panel on each phase from cable spouts with all circuit breakers racked in service and on position.

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

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

7.

Perform electrical tests on all component equipment as per SEC approved procedures: Circuit breakers. Current transformers. Voltage transformers. 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. Contact resistance separate test for CB and all DS. 10. Functional test of all electrical interlocks. 11. Functional test of trip free and anti pump circuits. 12. Functional test of local, alarm and indications. 13. Functional test of remote, alarm and indications. 14. Minimum control voltage trip and close operations. 15. Check and test capacitor trip circuit (if applicable).


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

18. Functional checks of breaker operation counter. 19. Timing test open/close using an electronic oscillograph. 20. 21. For minimum oil breakers, test insulating oil for dielectric strength.




ITEM Description DONE Remarks ASTM D-877 (with 2.5 mm gap)



T A B L E - 2 TEST VOLTAGE LEVEL FOR MEDIUM VOLTAGE METAL CLAD SWITCHGEAR

Switchgear Ratings

AC Test Voltage Time Period

11KV

25kV 60 Hz

60 Sec

13.8 kV

30 kV 60 Hz 60 Sec

33 & 34.5 kV

56 kV 60 Hz 60 Sec




1.13 Metal Enclosed Bus Duct


1. Inspect for physical damage or defects. 2. Check bus arrangement for conformance with approved drawings. 3. Check tightness of all bolted connections (torque wrench method). 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.




1.14 Indoor and Outdoor Bus Structures



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




1.15 Indoor Circuit Breakers


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


13. For pneumatic operating mechanisms: For pneumatic operating mechanisms: 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, and 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. 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).


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, and 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.




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).


heater current.




ITEM DESCRIPTION DONE REMARKS 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 Measure motor starting and running 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. Checks the correct functioning of interlocks and limit switches.



1.16 Outdoor Circuit Breakers



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.



10. For pneumatic operating mechanisms: a. Check the compressor, air piping, valves, pressure gauges, air filter, water trap and switches for damage or defects.

b. Calibrate the air pressure gauges. c. Check the setting of air pressure switches (compressor start/stop, alarm, and 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. 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).


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,

and 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



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.

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.




1.17 Disconnect & Grounding Switches



1. Inspect for physical damage and 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, CB’s, etc.).

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

17. Check mechanical alignment and contact gap "if applicable"



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


3. Measure motor starting and running current.

4. Check position-signaling contacts (if applicable).





5.

For motor operating mechanisms: a. Check mechanism cabinet grounded. b. Check correct setting of motor limit switch (open/close). c. Check correct operation of all auxiliary “a” and “b”

contacts. d. Measure switches 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 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.

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




1.18 Circuit Switchers



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.



1. Resistance of main current path (terminal to terminal) at 100 Amps DC.

2. Functional check of all electrical interlocks. 3. Measure motor starting and running current. 4. Check position-signaling contacts (if applicable). 5. 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 switches 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.

6. Check shunt trip device operation. 7. Verify proper operation sequence of interrupters and disconnects. 8. Insulation power factor test of the interrupters. 9. Timing test of the interrupter contacts with electronic oscillograph.




1.19 LV AC/DC LV AC/DC Board and Circuit Breakers (380/220/127V)


ITEM DESCRIPTION DONE REMARKS 1. Main circuits Continuity Test for tightness of joints and bolts.

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

3. Phasing check.

4. Check & verify for all MCCBs ratings as per requirement.

5. Single pole Trip Test of all MCBs by current injection as per manufacturers given curve.

6. All Ampere & Volt meter to be calibrated.

7. Insulation Test on all Secondary wiring & cables.

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

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




1.20 230kV and 380kV XLPE Cables


ITEM Description DONE REMARKS

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.












16 Single Core Cable connected between Power Transformer and SWGR shall be single point earthed at SWGR side and at floating side SVL (sheath voltage limiter) should be installed.

17 Check Single point or both ends, via voltage limiter as per approved design.

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

19

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







ITEM Description DONE REMARKS1. Phase checking for conductor & sheath bonding. 2. Conductor resistance, Capacitance and inductance measurement test

3. Sheath DC high voltage test (10kV DC for 1 min.) and 5 kV DC insulation tester before and after high voltage/ 24 hour Soaking test.

4. Anti corrosion sheath test


< 2 Ω located inside substation <10 Ω if located far from substation)

6. Zero and positive sequence impedance measurement 7. SVL (Sheath voltage Limiter)test By2.5kV DC insulation tester 8. Insulation resistance test of cable by 5kV DC


10. Contact resistance test on link boxes (less than 20 µΩ) 11. Metallic sheath continuity test (if applicable) 12. Cable profile test.




16.





S/S Name / No:………….. Bay No.: ………………….

1.21 230 kV and 380kV LPOF Cables



1. Inspect for physical damage or defects 2. Check tightness of all bolted connections (torque wrench method) 3. Check for proper cable bolted connections


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




9. Pressure test of all associated oil piping 10. Check that phases are identified and color coded 11. Single Core Cable connected between Power Transformer and


12. Availability of oil sampling facility valve arrangement. 13. Check Single point or both ends, via voltage limiter as per approved

design

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

15. Oil flow test 16. Impregnation test 17. RGP test / DGA test

18.

For accessories (sealing terminations, pressure tank, gauges, instrument panels and link boxes), check the following as applicable: a. Nameplates installed and data is correct. 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






1.21.2 Electrical Test ITEM Description DONE REMARKS

1. Check Phasing for conductor & sheath bonding 2. Conductor resistance, Capacitance and inductance measurement test


4. SVL (Sheath voltage Limiter)test by2.5kV DC insulation tester 5. Anti corrosion sheath test

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

less than 2 Ω for location inside substation <10 Ω for located far from substation

7. Zero and positive sequence impedance measurement 8. Insulation resistance test for conductor


10. Contact resistance test on link boxes ( less than 20 µΩ ) 11. Oil pressure gauge Function test 12. Shield continuity test 13. Cable profile test 14. Insulation oil dielectric breakdown test and water content test.

15.







1.22 110kV and 115kV and 132kV XLPE cables



1. Inspect for physical damage or defects. 2. Check tightness of all bolted connections (torque wrench method) 3. Check for proper cable bolted connections


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

6. Link box tightness check




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. Inspection of label inside link boxes and water proofing test 14. Check cable entry path trench as ducts are to be properly sealed.

15. Check irregularities of outer jacket formed by non uniform shield wire distribution.

16. Check/inspect the cable outer jacket for any physical damage or irregularities.

17. Check/inspect the transposition of cable phases

18. Check for the cross connection of cable metallic sheath in cross bonding system

19. Check the rubber seal in the cable clamps to avoid any damage to cable outer jacket

20. Check the insulating shrouds are installed at the base of cable terminations

21.

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








1. Check Phasing for conductor and sheath bonding.




5. Cross – bonding verification test

Sheath Current < 3 % the Sheath Current should be

3%, the current due to induction of neighboring circuits should be considered and the limit should be 3%+current due to external circuits

6. Zero and positive sequence impedance measurement

7. SVL (Sheath/surge voltage Limiter) test by 2.5kV DC insulation tester


<2 Ω for located inside substation <10 Ω for located far from S/S

9. Contact resistance test on link boxes ( less than 20 µΩ ) 10. Metallic sheath continuity test (if applicable) 11. Anti corrosion sheath test 12. Cable profile test




16.

AC High voltage test for all new cables, but if old portions are involved then soaking for 24 hours at rated voltage. (For equipments/cables projects, where old portion is involved, the decision to apply HV testing shall be decided by the mutual






agreement between CSD and Contractor.)

1.23 110kV and 115kV and 132kV LPOF Cables

1.23.1 Mechanical Check and Visual Inspection ITEM Description DONE REMARKS

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





9 Pressure test of all associated oil piping 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 Availability of oil sampling facility valve arrangement.


14 Oil flow test 15 Impregnation test 16 RGP test / 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), cheek the following as applicable:

a. Nameplates installed and data is correct. b. Link box tightness check. c. Inspection of label inside link boxes and water proofing test d. All valve positions according to design (open/closed). e. Calibrate pressure gauges and pressure switches. f. Oil pressure. g. No oil leaks. h. Condition of paint work i. All bolted connections






1. Check Phasing for conductor & sheath bonding.


3. Conductor resistance, Capacitance and inductance measurement


5. Cross – bonding verification test Sheath Current <

3 %

6. SVL (Sheath voltage Limiter) test by2.5kV DC insulation tester


less than 2 Ω for location inside substation <10 Ω for located far from S/S

8. Contact resistance test on link boxes 9. Oil pressure gauge Function test. 10. Shield continuity test 11. Anti corrosion sheath test 12. Cable profile test 13. Insulation oil dielectric breakdown test and water content test.

14.






1.24 69 kV XLPE power Cables


ITEM Description DONE REMARKS 1. Inspect for physical damage or defects 2. Check tightness of all bolted connections (torque wrench method) 3. Check for proper cable bolted connections


5. Check for proper cable support ,clamping ,trays, blocking 6. Link box tightness check




10. Check that phases are identified and color coded 11. Single Core Cable connected between Power Transformer and


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. Check irregularities of outer jacket formed by non uniform shield

wire distribution.

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



ITEM Description DONE REMARKS 1. Check Phasing for conductor and sheath bonding.


3. SVL(sheath voltage limiter)test By 2.5kv DC insulation tester 4. Anti corrosion sheath test


less than 2 Ω for location inside substation <10 Ω for located far from


PART II: MECHANICAL CHECKS, VISUAL INSPECTIONS & ELECTRICAL TESTS Check list S/S Name/ No.: ……………………


Bay No.: ……………..


S/S

ITEM Description DONE REMARKS 6. Zero and positive sequence impedance measurement 7. 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. Metallic sheath continuity test (if applicable) 12. Cable profile test

13.





1.25 13.8 kV and 33 kV XLPE Power Cables



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.

6. Check tightness of all bolted connections (torque wrench method). 7. Check that phases are identified and color coded. 8. Check cable entry path trench as ducts are to be properly sealed. 9. Verification of exact route length as per approved drawings from


10. 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.(1000v DC insulation

resistance) IR for

sheath > 10 Meg-ohms

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 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.





1.26 LV Cables



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. 7. Check cable entry path trench as ducts are to be properly sealed. 8. Visual Inspection, 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.



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1.27 Control Cable


ITEM DESCRIPTION DONE REMARKS 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. Check the path/separation of control & power cables 9. Visual inspection, size and rating confirmation. 10. Size checking against rating required.



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

Mega-ohms



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1.28 Pilot Cables



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




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

Mega-ohms 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 Mega-ohms

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

Mega-ohms 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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(Table2.1)Test Voltage Levels for High Voltage Power Cables




13.8 kV XLPE POWER CABLES

2Uo = 16 kV AC or


60

60


2Uo = 38 kV AC or


60

60


2Uo = 80 kV AC or


60

60 110/115 kV XLPE/LPOF

POWER CABLES 2Uo = 128 kV AC 60


2Uo = 152 kV AC 60


2Uo = 265 kV AC 60

380 kV XLPE/LPOF POWER CABLE

260kV 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




LV Cables 2.5 kV DC Insulation Tester 1



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

1



If IR < 1000 Mega-ohms, 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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1.29 Overhead Lines

1.29.1 Mechanical check and Visual inspection


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 to run-off away 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 poles’ type and size 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 are being 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 bolts’ 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, torn. The rod should not be exposed at any of its location.

17.

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

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



Bay No.: ……………..


energized. ITEM DESCRIPTION DONE REMARKS

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

20. Check that all jumpers are installed correctly. Make sure of correct clearance between jumper and structure as well as with other phases.

21. Check that overhead shield wire / OBGW 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 are meeting company standards.

24. Check circuit / phase identification plates, structure number, 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 with cable (if applicable).

28.

For terminal compound, check the following, if available, as per contract:

a. Outdoor equipment such as surge arresters, CVT’s, 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.

30.

Regarding to the spacer dampers and vibrations on the 380kV Overhead Transmission Lines the following should be observed:-

a. Installed as per Manufacturer Instruction b. Spacer Damper Locations are as per the approved "In-Span

Position Table" c. Alignment of Spacer Dampers are perpendicular to Installed

Using Manufacturer d. Recommended Tools.

See check list item 3.29.3



1 Perform phase sequence / rotation check.

2 Perform sequence impedance and susceptances tests and mutual impedances (both zero and positive sequence for double circuits



Bay No.: ……………..


lines

3 Check tower foot earth resistance as per company standards. ITEM DESCRIPTION DONE REMARKS

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

5 Perform continuity and conductivity test

6 Perform Phase conductor insulation resistance test. 5kV for 1 minute

1.29.3 Check list

CHECK LIST FOR SPACER DAMPER INSTALLATION

Transmission Line Voltage Level Location (Area) Contractor Name Contract No Spacer Damper Manufacturer

Span No.

Installed as per Manufacturer Instruction

Spacer Damper Locations are as per the

approved "In-Span Position Table"

Alignment of Spacer Dampers are

perpendicular to

Installed Using Manufacturer Recommended Tools.

Remark

Verified

Not Verified Verified

Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Verified


Not Verified

Verified

Not Verified

Verified

Not Verified

Inspected by Contractor Supervisor: Verified By SEC Rep.: Date:



Bay No.: ……………..


1.30 Protection and Control Panels.

1.30.1 Protection and Control Panels-Mechanical Checks and Visual Inspections ITEM DESCRIPTION DONE REMARKS

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.


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.




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.


1.30.2 Internal Panel Wiring Tests


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,



Bay No.: ……………..


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.

ITEM DESCRIPTION DONE REMARKS 1. 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. a. CT Circuit Confirmation b. Inject AC current at about 50% of the rated current into one

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

c. 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.

d. 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.

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

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



Bay No.: ……………..


3. VT Circuit Confirmation a. Connect a fused or current limited adjustable three phase, four

wire voltage sources 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 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.

1.30.3 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.



Bay No.: ……………..


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.

1.30.4 Panel Device Tests


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. 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.



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iii.Operation timing at 80% and 100% 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.




Bay No.: ……………..


General Mechanical Checks & Visual Inspection of Relays. a. Inspect for defects and physical damage from shipping and

handling. b. Any clamps or rubber bands used to secure moving parts to

prevent damage during transit should be removed after installation and before commissioning.

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

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

e. Check case cover and gasket for proper seal against dust. f. Check all installed equipment nameplate information for

compliance to approved drawings and equipment /material lists. g. Check that the relay serial number on the module, case and cover

are identical. h. 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.

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

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

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

l. 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. Check Ferrules.

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

n. Case earthing checked o. Auxiliary power supply rating checked and wiring checked for

proper polarity. p. Verify connections as per approved drawings. q. Use of ring type terminals for wire termination for current circuit

wires.

General Electrical Tests of relays. a. Check that rating of the relay agree with the Auxiliary Supply to

which it is connected. b. Check that DC Supplies are wired with the correct Polarity.




Bay No.: ……………..


c. Check that the frequency of the relay supply is compatible with the system’s rated frequency.

d. Verify that the secondary current for current operated relays matches the used CT secondary current

e. Verify proper phase shorting for CT field test switches and test plugs used with current operated relays.

f. Check that the relay nominal input voltage matches the VT voltage.

g. Verify proper case shorting facility for current operated draw out type relays.

h. Make sure that all trip circuits are using high burden trip contacts from the protection relays.

i. Make sure that the low burden annunciation contacts are used only in low burden circuits such as annunciation and indication.

j. Verify that the number of contacts and the contact. configuration (NC, NO ,CO) is the same in the drawing as it is in the relay

a. Voltage operated relays to have a pickup voltage less than 80% of the rated substation voltage to allow for proper operation of the relay even during substation DC under-voltage condition.

b. Check Annunciation LEDs and flags. c. Check Annunciation contacts d. Check Binary inputs. e. Check binary outputs and output contacts f. 500 V insulation tests shall be conducted between:

(i) All electrically isolated circuits. (ii)All circuits and earth.

g. Ensure that the error percentage between set values and actual values within the acceptable limit for all tested settings and check all error limits are included in test formats.

h. Check Watchdog or Internal Relay Fail contacts

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, 270 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.



Bay No.: ……………..


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 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.

1.30.5 Functional Checks


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.



Bay No.: ……………..



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 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



Bay No.: ……………..



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).


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 over current etc.) prevent operation of the ABTS.

c. Prove scheme for opening of bus 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.



Bay No.: ……………..


1.30.6 Energization ITEM DESCRIPTION DONE REMARKS

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 alarm relay settings are finalized and the relays are locked. g. Relays that have a backup battery for memory storage have

their batteries installed and the temporary battery covers removed.

h. All switchgear and other power equipment testing are completed.

i. All protection equipment is properly labeled. j. All fire/smoke alarm systems are fully tested and in service. k. All necessary fire fighting equipment is on site and accessible

without obstruction. l. 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.



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.






1.31 Station Batteries



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 voltage of each cell

or unit and battery terminals float voltage. c. Disconnect the battery charger and any other load on the

battery.

Room temperature shall be between 25 and 30 °C.





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.

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




1.32 Battery Charger



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

5. Check that all Alarm relays shall be auto-reset.

1.32.2 Electrical Test ITEM DESCRIPTION DONE REMARKS

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



Bay No.: ……………..


1.33 AC Distribution Panels



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

2. Verify circuits layout for conformance with breaker directory drawing

3. Inspect and verify ACDB Rating Plate, check bus-bar rating, short circuit withstand current & main MCCBs rating at 55oC.





ITEM DESCRIPTION DONE REMARKS1. Insulation test of all buses and wirings 2. Phasing check 3. Functional check of main power contactor (or breaker) 4. Functional check of each branch breaker

5. Calibrate voltmeters, ammeters and watt-meters

6. Functional check of meters and phase selector switches


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.

11. Apply trip test for all MCCBs by pole- pole current injection method



Bay No.: ……………..


1.34 DC Distribution Panels



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

2. Verify circuits layout for conformance with breaker directory drawing

3. Inspect and verify DCDB Rating Plate, check bus-bar rating, short circuit withstand current & main MCCBs rating at 55oC.





ITEM DESCRIPTION DONE REMARKS1. Insulation test for all busses and wirings 2. Polarity check 3. Functional check of main breaker 4. Functional check of each branch breaker 5. Calibrate voltmeters, ammeters and watt-meters 6. Functional check of meters and phase selector switches


8. Functional check of under voltage protection/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




1.35 LV AC Auto-Transfer Schemes/Switches



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. 4. Check tightness of all bolted connections (torque wrench method). 5. Check that all grounding is correct and securely connected (including

neutral bus).

6. Check mechanical/electrical interlocks.

1.35.2 Electrical Tests 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.




1.36 GROUNDING SYSTEM


ITEM TEST DESCRIPTION DONE REMARKS

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 to conform with standard requirements

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


ITEM TEST 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

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

4. Step and touch voltage measurement




1.37 Switchgear Air Compressor Systems


ITEM DESCRIPTION DONE REMARKS 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. Check that air compressors are fitted with: a. Automatic drain valve. b. Manual drain valve. c. Pressure relief valve. d. Oil level sight glass.

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.

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.



Bay No.: ……………..


1.38 HVAC Systems



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 and 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:


b. Crank case heater. c. High and low pressure cut-out manual reset.

For semi-hermetic reciprocating compressors:




Bay No.: ……………..


b. Oil level sight glass.

ITEM DESCRIPTION DONE REMARKS 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. 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.



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. Wire splices shall be avoided as much as possible

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:

a. Preliminary test. b. Pressure test. c. Leak test.



Bay No.: ……………..


d. Control test. e. Operation 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.




1.39 Dry Type Transformer



1. Check nameplate for correctness 2. Check tightness of all bolted connections(torque wrench method

3. Check that all grounding is securely connected ,including star point neutral

4. Perform all specific checks per manufacturer instructions 5. Check proper operation of all auxiliary devices (if applicable)


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 circuits functional tests



S/S Name / No:………….. Bay No.: ………………….

1.40 Ring Main Unit (RMU)

1.40.1 Mechanical Check and Visual Inspection ITEM DESCRIPTION DONE REMARKS

1. Check nameplate information for correctness 2. Check for damage to the body or the fuses 3. Check the interlock system 4. Check the level of insulation medium (SF6, Oil…etc)


1. Phasing

2. Insulation Resistance 5kV for 1

minute 3. Contact resistance using low resistance copper bar in place of fuses.

4. HV Test at 3

2geRatedVolta

5. Earth Fault indicator test and function tests (trip / alarm contacts)




S/S Name / No:………….. Bay No.: ………………….

1.41 Capacitor Bank Test




2. Check nameplate information for correctness. 3. Check for overall body deformation.

4. Check tightness of the bolts according to specifications

5. Check leakage for any Cell of capacitors 6. Check that all grounding cables are securely connected

7. Check for any damaged paint for capacitors. 8. Check surge arrestor connections. 9. Check capacitor bushing tightness and bird proof capes. 10. Check for bushing cracks. 11. Check for proper termination. 12. Check for CT locations physically, 13. Check for VT locations physically.



1. Check of test and measuring instruments calibration certificates. 2. Check of condition of battery cells of the T&M instruments. 3. Measure each individual capacitance. 4. Capacitance bank insulation test. 5. Capacitance bank measurement test. 6. Capacitance and dissipation factor measurement test. 7. Check individual insulation resistances. 8. Perform all specific tests per manufacturer's instructions. 9. Megger test phase to phase. 10. Capacitance bank neutral unbalance measurement.





1.42 CAPACITOR AND ASSOCIATED REACTOR (REACTOR TEST)




2. Check nameplate information for correctness. 3. Check for overall body deformation. 4. Check tightness of the bolts according to specifications.

5. Check of foreign particles between the layers of the reactor coils. 6. Check that all grounding cables are securely connected.

7. Check the quality of the paint for reactors. 8. Check of any insulation cracks. 9. Check for proper termination.



1. Check of test and measuring instruments calibration certificates.

2. Check of condition battery cells of the Test and Measurement instruments.

3. Check main condition current path connection contact resistance. 4. Measure the insulation resistances of each phase to ground. 5. Measure the inductance of the harmonic filter inductors. 6. Temperature measurement at different joints after energization

TRANSMISSION CONSTRUCTION STANDARD TCS-P-105, Rev. 01 ATTACHMENT # 15 CHECK LIST S/S Name / No.: …………………… Bay No. - ……………..


1.43 Static VAR Compensation System

1.43.1 Pre-Commissioning Tests and Safety Measures

ITEM DESCRIPTION DONE REMARKS 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.

1.43.2 SVC Transformer Tests

See Oil Filled Power Transformers, Section 3.1.

1.43.3 Harmonic Filters: Capacitors and Associated Inductors



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.

b. Electrical Tests


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. 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.

1.43.4 Thyristor Controlled Reactor



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.

b. Electrical Tests


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.

1.43.5 Cooling System Component Tests



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 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).



b. Electrical Tests


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. Check PLC internal battery if present and note the date of 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.

1.43.6 SVC System Controller Computer




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.



b. Electrical Tests 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.

ATTACHMENT # 15 CHECK LIST S/S Name / No.: …………………… Bay No. - ……………..




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.

1.43.7 Protective Relay Tests and Check of Protection Schemes




terminal

b. Electrical Tests 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.

1.43.8 SVC Energization: Sequence of Events and On-Load Tests

a. Electrical Tests


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

contractor for the Energization, copy to the Control Center.



Bay No.: ………………….

ITEM DESCRIPTION DONE REMARKS 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).

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.

33. Keep running for one day in auto mode.




Bay No.: ………………….

ITEM DESCRIPTION DONE REMARKS 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




Bay No.: ………………….

2.0 CHECK LIST FOR TESTING PROTECTION RELAYS

2.0 CHECK LIST OF PROCEDURE FOR TESTING PROTECTION RELAYS 97

2.1 General Mechanical Checks & Visual Inspection 98 2.2 General Electrical Tests 99 2.3 Guidelines for Testing Digital& numerical Protection & control Relays and IED’s 100 2.4 Auxiliary Relays 103 2.5 Timers (62) 105 2.6 Over/Under-Voltage Supervision Relays (59/27) 106 2.7 Compensation Voltage Protection -59ND 107 2.8 Trip Circuit Supervision 108 2.9 Definite Time Over-Current & earth fault protection relay 111 2.10 Inverse Definite Minimum Time (IDMT) Over-Current & earth fault protection

relay 112





Bay No.: ………………….

2.1 General Mechanical Checks & Visual Inspection



2. Any clamps or rubber bands used to secure moving parts to prevent damage during transit should be removed after installation and before commissioning.

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


5. Check case cover and gasket for proper seal against dust.

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

7. Check that the relay serial number on the module, case and cover are identical.

8.

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.




12.

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. Check Ferrules.


14. Case earthing checked

15. Auxiliary power supply rating checked and wiring checked for proper polarity.

16. Verify connections as per approved drawings.

17. Use of ring type terminals for wire termination for current circuit wires.




Bay No.: ………………….

2.2 General Electrical Tests



2. Check that DC Supplies are wired with the correct Polarity.

3. Check the relay power consumption during operation at nominal rated voltage.

4. Check that the frequency of the relay supply is compatible with the system’s rated frequency.

5. Verify that the secondary current for current operated relays matches the used CT secondary current

6. Verify proper phase shorting for CT field test switches and test plugs used with current operated relays.

7. Check that the relay nominal input voltage matches the VT voltage.

8. Verify proper case shorting facility for current operated draw out type relays.

9. Make sure that all trip circuits are using high burden trip contacts from the protection relays.

10. Make sure that the low burden annunciation contacts are used only in low burden circuits such as annunciation and indication.

11. Verify that the number of contacts and the contact configuration (NC, NO ,CO) is the same in the drawing as it is in the relay

12. Voltage operated relays to have a pickup voltage less than 80% of the rated substation voltage to allow for proper operation of the relay even during substation DC under-voltage condition.

13. Check Annunciation LEDs and flags. 14. Check Annunciation contacts 15. Check Binary inputs. 16. Check binary outputs and output contacts

17. 500 V insulation tests shall be conducted between: a) All electrically isolated circuits. b) All circuits and earth.


19. Check Watchdog or Internal Relay Fail contacts




Bay No.: ………………….

2.3 Guidelines for Testing Digital& numerical Protection & control Relays and IED’s



2. Devices that have multiple standards of characteristics to be tested as per SEC used standards (example IEC standard curves for Over-Current Time Inverse characteristics)


4.


Ref IEC 61850-5 , Clause 13.7.4






9.




Ref IEC 61850-10, Clause 6.2.4.16.1


Ref IEC 61850-10, Clause 6.2.4.16.2




Bay No.: ………………….








18. The reference values (% tolerance allowed) for each device should be compulsory mentioned on test report



21.

Testing of numerical control:

Mimic and single line diagram on the relay display has to be checked according to approved single line diagram of SS Control configuration and all functions the relay has to be checked according to approved schematic diagram and approved configuration. Interlocking logics have to checked and studied according to approved scheme and conditions. Check of all breaker, disconnector and earth switch positions. The position indications are checked by local operation in the field and the physical position of every device has to be compared with the shown position on the local mimic, the displays of the relays and on the SAS. Check of all breaker, disconnector and earth switch commands. The commands have to be checked for the possible modes (Local, Emergency & Remote.). Local operation mode at the relay display can be selected by selector button on the relay display. Every switching devices has to be operated (open and close) in the local mode. Remote mode at SAS at the relay display can be selected by selector button on the relay display. Every switching devices has to be operated (open and close) in the remote mode. The proper LED indication has to be checked. The interlocking logic for local and remote operation can be either checked from locally from relay display or remotely from SAS. These conditions have to be checked according to the






approved base design document. Eventually the system contains an interlocking override function which has to be checked by the certain instance (e.g. UBC or SAS.)

22. Checking of close blocking by lock out relay. 23. Checking of synchrocheck function

REMARK:

SUBSTATION AUTOMATION SYSTEM procedures must be submitted from suppliers at least 6 months before starting commissioning for study by SEC.



Bay No.: ………………….

2.4 Auxiliary Relays

Auto Reset Auxiliary Relays (Auto Reset, Hand Reset, Electrically Reset, Bi-Stable, Trip Lockout Relay (86) & Trip Auto Reset Relay (94)

2.4.1 General Mechanical checks and visual inspection.



2.


3. Check condition of any connectors, contacts alignment and travel. 4. Check armature gap. 5. Check Lockout mechanism. 6. Check Reset mechanism.



1. General Electrical Tests As per 4.2 2. Check the continuity of the contacts. 3. Check the resistance of all output contacts. 4. Check the pick up voltage and current of operating Coil. 5. Check the AUTO-RESET function 6. Check the Reset mechanism 7. Check pick up voltage and current of Reset Coil. 8. Check Drop off voltage and current of Reset Coil.

9. Check the operating time of the Reset Coil at lowest nominal supply voltage

10. Check the operating time of the operate Coil at lowest nominal supply voltage.

11. Check Operate Coil and Rest Coil power consumption during operation at nominal rated voltage.

12. Check operate and Reset Coil resistance. 13. Check external Reset input if applicable. 14. Check Change-Over time for contacts which makes/breaks.

15. Check power consumption of operate and Reset Coil.

16. Verify trip test for circuit breaker and closing block.

17. Check Drop off voltage and current of operating Coil.

18. Check the operating and Reset time at lower nominal supply voltage.

19. Check Relay Burden during operation at nominal rated voltage. 20. Check Operating coil resistance.






21. Check the reset ratio ( reset ratio = drop off / pick up)

22. Check power consumption of the relay.

23. Perform the functional test of the relay for which it is being used.

24. Check operation indicator /Flag/LED function.



Bay No.: ………………….

2.5 Timers (62)

2.5.1 Mechanical checks& visual inspection



2.


3. Check condition of any connectors, contacts alignment and travel.

2.5.2 Electrical tests ITEM DESCRIPTION DONE REMARKS


2. Ensure correct values of external resistors (where applicable) and check these are wired to the correct relay terminals.

3. Check Pick-up and Drop-off Voltage. 4. Check current at Pick-up\ drop-off voltage. 5. Check the contact operating time pickup\ drop-off Test. 6. Check the burden at rated voltage. 7. Check Timing at different points setting.

8. Check that trip indicator operates correctly and can be reset using reset mechanism. For versions fitted with LEDs trip indicator check proper operation of LEDs.

9. Check that contact operate by doing continuity check.

10. Check that necessary trip and alarm circuits are energized according to relevant Schematic diagram by operating the relay with trip and alarm links restored.

11. Timer range to match drawing

2.5.3 Related Tests ITEM DESCRIPTION DONE REMARKS

1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3





2.6 Over/Under-Voltage Supervision Relays (59/27)

2.6.1 General Mechanical checks, visual inspection



2. Ensure the correct values of external resistors (where appropriate) are wired to the correct relay terminals.

3.


4. Check condition of any connectors, contacts alignment and travel. 5. Check Current Supervision feature in Under Voltage relay.




4.3 if applicable

2. Check measurements and error ratio

3. Check over voltage pick-up and drop-off and reset ratio.

4. Check under voltage pick-up and drop-off and reset ratio

5. Check low voltage blocking

6. Time-voltage characteristic test.

7. Instantaneous unit test.

8. Check binary inputs and outputs and annunciations.

9. Check Nominal contact voltage AC/DC.

10. Check for visual indication for power supply, pickup and reset.

11. Check Current Supervision feature in Under Voltage relay. If applicable.

2.6.3 Related Tests ITEM DESCRIPTION DONE

1. Testing the Final Setting as per approved setting 2. Final Trip Test As per 5.11



S/S Name / No:………….. Bay No.: ………………….

2.7 Compensation Voltage Protection 59ND







& 4.3 if applicable

2. Check that rating of the relay agree with the auxiliary supply to which it is connected.

3. Check the Rated Bus Voltage & Rated Neutral voltage and Rated Frequency are educated to SS facilities.

4. Check relay applied configuration according to approved configuration and to schematic drawing.


6. Check all binary inputs and outputs contacts, Indication LEDs and alarm and trip indication messages on LCD and event & fault recorder.

7. Check the VT MCB trip will block the protection element and check Led's for MCB /VT failure or fuse failure.

8. Check test switch/plug for correct function. 9. For Numerical relays perform Secondary injection measurements

for neutral voltage and Bus voltage and compensation voltage and voltage difference.

10. Check The compensation voltage setting saving during DC off. 11. Check Over Voltage difference pick-up and drop-off for Neutral

voltage and Bus voltage (low set stage).

12. Check Over Voltage difference pick-up and drop-off for Neutral voltage and Bus voltage (high set stage).

13. Check Tripping Time of over voltage difference (low set stage).

14. Check Tripping Time of over voltage difference (high set stage).

15. Check the approved applied settings.






S/S Name / No:………….. Bay No.: ………………….

2.8 Trip Circuit Supervision

2.8.1 Trip Circuit Supply Supervision

a. General Mechanical Checks & Visual Inspection



2.



b. Electrical tests


1. General Electrical Tests As per 4.2 2. Measure Trip Supply and Alarm Supply. 3. Check Protective fuse rating.



7. Check pickup Voltage / Drop –off voltage and measure current.

8. Check power consumption when the relay is energized. 9. Check Relay Coil Resistance. 10. Initiate Alarm by removing fuse. 11. Check Nominal contact voltage AC/DC. 12. Check for visual indication for power supply, pickup and reset.

2.8.2 Trip Circuit Supervision, without pre-closing supervision

a. General Mechanical checks, visual inspection



2.






S/S Name / No:………….. Bay No.: ………………….

b. Electrical tests




3. Check that DC Supplies are wired with the correct polarity. 4. Measure Trip Supply and Alarm Supply. 5. Check Protective fuse rating.



9. Check pickup / Drop –off for both voltage and current of the operating coil.

10. Check power consumption when the relay is energized. 11. Check operating Coil Resistance.

12. Check voltage across relay coil when circuit breaker is open and closed.




2.8.3 Trip Circuit Supervision, with pre-closing supervision

a. Mechanical checks & visual inspection



2.



b. Electrical tests







S/S Name / No:………….. Bay No.: ………………….

ITEM DESCRIPTION DONE REMARKS 3. Check that DC Supplies are wired with the correct polarity. 4. Measure Trip Supply and Alarm Supply. 5. Check Protective fuse rating.



9. With the C.B. Open Check pickup / Drop –off for both voltage and current of Operating coil-1.

10. With the C.B. closed Check pickup / Drop –off for both voltage and current of Operating coil-2.

11. Check power consumption when the relay is energized. 12. Check operating Coil Resistance.

13. Check voltage across relay coil when circuit breaker is open and closed.







S/S Name / No:………….. Bay No.: ………………….

2.9 Definite Time Over-Current & earth fault protection relay




2.


3. Check condition of any connectors, contacts alignment and travel. 4. Check armature gap.


ITEM DESCRIPTION DONE REMARKS1. General Electrical Tests 2. Check for External resistors, where applicable. 3. Check relay configuration.

4. Check that protection relay settings have been entered correctly.


6. Check Pick-up & Drop off Values of Over Current for all phases & Earth fault (Low set stage.) ( for several setting adjustments )

7. Check Tripping Time of Over Current for all phases & Earth fault (Low set stage.) ( for several setting adjustments )


9. Check Tripping Time of Over Current for all phases & Earth fault (High set stage.) ( for several setting adjustments )

10. Witness binary inputs and outputs and annunciations.

11. Check displayed measurements in primary or secondary values if applicable.

2.9.3 Related Tests






S/S Name / No:………….. Bay No.: ………………….

2.10 Inverse Definite Minimum Time (IDMT) Over-Current & earth fault protection relay







4.3 if applicable

2. Check displayed measurements in primary or secondary values if applicable.

3. Check for External resistors, where applicable.


5. Check Pick-up & Drop off Values of Over Current for all phases & Earth fault (Low set stage.) (for several setting adjustments)

6. Check Pick-up & Drop off Values of Over Current for all phases & Earth fault (High set stage). (for several setting adjustments)

7. Check Normal inverse characteristics on different multiples of plug setting /current setting. (For all 3 phase over current & earth fault)

2x, 5x, 10x Is

8. Check Very inverse characteristics on different multiples of plug setting /current setting. (For all 3 phase over current & earth fault)

2x, 5x, 10x Is

9. Check Extremely inverse characteristics on different multiples of plug setting /current setting. (For all 3 phase over current & earth fault)

2x, 5x, 10x Is

10. Check Long time inverse characteristics on different multiples of plug setting /current setting. (For all 3 phase over current & earth fault)

2x, 5x, 10x Is

11. Check Tripping Time of Over Current & Earth fault (High set stage.)

12. Check the over current & earth fault indication LED's, display and fault & event recorders.

13. Check tripping indication.






S/S Name / No:………….. Bay No.: ………………….

2.11 Circuit Breaker Fail (CBF) Protection (50/62)




2.11.2 Electrical test ITEM DESCRIPTION DONE REMARKS


& 4.3 if applicable

2.

Measurements a. pick up (PU) b. drop out (DO) c. ratio DO/PU %

3. Check CBF for mechanical protection initiate low current mode in the relay if applicable

If applicable

4. Check relay operating time for all re-trip stages

5. Check relay setting PLUG TAP x MULTIPLIER

6. Check annunciation LEDs 7. Check annunciation contacts 8. Contact resistance of tripping and alarm checked


1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. End to End test




S/S Name / No:………….. Bay No.: ………………….

2.12 Bus Bar Differential Protection RELAY (87B)

2.12.1 High Impedance Bus Bar Differential Protection



1. General Visual Inspection As per 4.1 2. Indications checked 3. CT Supervision indication and flags should be latching

4. CT ratios, CT Matching for all CT’s in the same zone or use of correct matching CT’s and CT grouping per protection zone.

b. Electrical test



4.3 if applicable

2. Check power supply status

3.

Check operating and drop out a. pick up b. drop out c. reset factor

Check at many operating setting values and final setting.

4. Check relay operating time ( at many setting values and final setting)

5.

Check tripping criteria (if applicable) OPTION 1: DIFFERENTIAL TRIPPING ENABLED TOGETHER WITH AN EXTERNAL STARTS. OPTION 2 : DIFFERENTIAL TRIPPING ENABLED TOGETHER WITH INSTANTANEOUS PICK UP OF BUS WIRE SUPERVISION OPTION 3 : DIFFERENTIAL TRIPPING ENABLED WITHOUT FURTHER CONDITIONS

6. Check bus wire supervision 7. Check disconnector replica. (Bus image) 8. Check stabilizing connection system with resistor & metrosil 9. Check all command relays 10. Check stability & sensitivity test by secondary injection 11. Verify that the total operating current in limits

12. Check the drawn secondary current in each element and verify that it's in limit for each element

c. Related Tests


1. Final Setting as per approved setting




S/S Name / No:………….. Bay No.: ………………….


2. Function Test & Scheme Check As per 5.7 3. Final Trip Test As per 5.11 4. On Load Test As per

5.23.6

2.12.2 Low Impedance Bus Bar Differential Protection


ITEM DESCRIPTION DONE REMARKS 1. General Visual Inspection As per 4.1 2. Indications checked

b. Electrical test


1 General Electrical Tests As per 4.2 &

4.3 if applicable

2

Measurements a. Measuring at every Bay Unit (BU). b. Measuring Idif and Istab Check Zone (CZ) at Central Unit

(CU). c. Take the reading of Idif and Istab of Bus Zone (BZ) and CZ

Form the testing equipment

3

Bus bar protection diff. current alarm test (at many setting values and final setting) Measure the pickup Measure the drop off Measure the time Check the relay LED

4 Bus bar protection diff. current

4.1

Pickup test (at many setting values and final setting) Measure the pickup current at CZ Measure the operate time at 2Isetting at CZ and check the relay LED. Measure the pickup current at BZ Measure the operate time at 2Isetting at every BZ and check the relay LED

5 Bus bar protection diff. current slope test

5.1

Bus zone. ( discrimination zone) Measure Idiff and Istab Calculate K = Idiff / Istab ( or according to relay manual)




S/S Name / No:………….. Bay No.: ………………….


5.2

Check zone Measure Idiff and Istab Calculate K = Idiff / Istab ( or according to relay manual)

6

Breaker failure protection test (if it is included in BBP relay) Measure pickup current (for all phases) Measure drop off current (for all phases) Measure time stage 1 Measure time stage 2 Check relay LED's Note that: CBF. Stg.-1 trip is related to the local feeder (bay unit).

CBF. Stg.-2 trip is related to the bus zone of that feeder (bay unit).

7 Breaker failure protection special test 7.1 CB faulty 7.2 Low current mode 7.3 End fault protection

7.4

Testing function Measure time of CB faulty (ms) Measure time of I < (ms) Measure time of End fault (ms) Check the relay LEDs

7.5

Diff. current super vision function checked a) Check Blocking during fault. b) Check Blocking till release c) Check Alarm without blocking

7.6

Isolator supervision function checked a) Check Blocking during fault. b) Check Blocking till release c) Check Alarm without blocking d) Blocking till acknowledge

7.7 All LED's checked 7.8 All binary input checked 7.9 All command relay checked

7.10 All signal relay checked

7.11

All bay unit checked a ) check DC Fail ( for both setting old status and close ) b ) check Comm. Fail ( for all Bays ) c ) check Out Of Service according to scheme according to relay

features availability and its manual) d ) check Maintenance (for all Bays)

7.12 Fault recorder checked 7.13 BF inter-trip with BB fault

7.14 Check the commissioning of the used Auxiliary contacts of breakers and Isolators are in line with Manufacture recommendation




S/S Name / No:………….. Bay No.: ………………….


7.15 Check the close command is terminated for all bays which take breaker status in account

7.16 Check power supply

c. Related Tests ITEM DESCRIPTION DONE REMARKS

1. Final Setting as per approved setting2. Stability & Sensitivity Test by simulation

of external and internal faultsAs per 5.12

3. Function Test & Scheme Check As per 5.7 4. Final Trip Test As per 5.11 5. On Load Test As per 5.23.6




S/S Name / No:………….. Bay No.: ………………….

2.13 Metrosil and Non Linear Resistor


ITEM DESCRIPTION DONE REMARKS 1. General Visual Inspection As per 4.1

2. Visual inspection of protective cover / shroud with high voltage caution label



1 Check the characteristics of the Metrosil


1 On Load TEST As per 5.23.6 (BB), 5.23.5 (REF) (measure metrosil current during on load stability)




S/S Name / No:………….. Bay No.: ………………….

2.14 Synchronism Check (25)





1 General Electrical Tests As per 4.2 & 4.3 if applicable

2 Check Measurements & percentage error 3 Check Voltage elements pickup and drop off 3.1 Check bus live range 3.2 Check bus dead range 3.3 Check line live range 3.4 Check line dead range 3.5 Check bus under voltage detector 3.6 Check line under voltage detector 3.7 Check difference voltage detector 4 Check Phase angle difference (∆) 5 Check Frequency difference (∆f) 6 Check timers (slip time and synchronism time) 7 Check under voltage block feature 8 Check binary output contact and indication led 9 Check blocking for synchronizing in case of FUSE FAIL OCCUR 10 Check Watchdog Contacts 11 Check Live Line Dead Bus Synchronism bypass 12 Check Dead Line Live Bus Synchronism bypass

13 Check Dead Line Dead Bus Synchronism bypass. (should be not bypass or according approved setting )



1. Final Setting as per approved setting 2. Function Test & Scheme Check




S/S Name / No:………….. Bay No.: ………………….

2.15 Distance / Impedance Protection relay (21)



1. General Visual Inspection As per 4.1 2. CT shorting checked 3. Indications checked 4. Contact resistance of tripping and alarm checked



1 General Electrical Tests As per 4.2 &

4.3 if applicable

2 Measurement checking: Secondary & primary values of V, I, angle, P& Q for all phases.

3 Relay configuration should be approved and signed by manufacturer & PED.

4 Distance protection pick up threshold 4.1 Check Phase fault current threshold detection (for all phases)

4.2 Check Earth fault current Thresholds 4.3 Check zero sequence voltage Threshold check 4.4 Check Dead line detection

5 Check all Zones reaches & Time Testing for all phases and all types of faults.

6 Distance directionality check 7 Distance Tele-protection scheme

7.1 Check POTT 7.1.1 Check Weak in-feed FUNCTION

7.1.1.1 Check Echo only 7.1.1.2 Check Echo and trip 7.1.1.3 Check under voltage pick up for local trip

7.1.1.4 Check Current Reversal Logic ( with POTT Scheme)

7.2 Check Permissive Under Reach ( PUTT ) (Z1 extension Acceleration)

7.3 Check Blocking Scheme

7.3.1 Check Current Reversal Logic ( with Blocking Scheme)

7.4 Check Unblocking Scheme 7.5 Direct transfer trip (DTT) 8 Check Power Swing function 9 Check Switch On to Fault SOTF

9.1 Check SOTF associated with distance protection 9.2 Check SOTF associated with back up over current




S/S Name / No:………….. Bay No.: ………………….

9.3 Check Instantaneous high speed SOTF O/C 10 Fuse failure monitoring

10.1 Check Fuse failure measurement

10.2 Check maximum voltage threshold U< ( 3 phase )

10.3 Check BI blocking (for VT failure) & indication.

11 Check Fault locator

12 Check Internal Recorder

13 Memory Voltage Test

13.1 Check Memory time measurement test

13.2 Check Memory voltage measurement test

14 Back Up Over Current Protection & Stub protection if applicable: (Emergency)

14.1 Definite time Pick up & drop off

14.2 Low set stage I>

14.3 High set stage I>>

14.4 Normal inverse characteristics

14.5 Very inverse characteristics

14.6 Extremely inverse characteristics

14.7 Long time inverse characteristics



1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. End to End test As per 5.17 5. On Load Test As per 5.23.3




2.16 Directional Over-Current and Directional Earth Fault Protection relay (67/67N)

2.16.1 General Mechanical checks and visual inspection ITEM DESCRIPTION DONE REMARKS

1. General Visual Inspection As per 4.1 2. CT shorting check




& 4.3 if applicable

2. Measurement: Injected quantities ( V and I ) 3. Measurement: P,Q,F, Directionality 4. Check the directional operating characteristic angle 5. Check the polarizing voltage (3Uo) Pick up and Drop off

6. Check Earth fault over current group (non directional& directional element )

7. Blocking of directional elements 8. Fuse fail 9. VT Fail 10. Communication Fail 11. Blocking Scheme with carrier received

12. Tele-Protection Schemes (Blocking, Unblocking, Directional Comparison, Direct Transfer Trip)

13. Check Fuse failure measurement 14. Check maximum voltage threshold U< ( 3 phase ) 15. Check BI blocking (for VT failure) & indication.

16. Check the VT MCB trip will block the directional element and the signal send

17. Memory Voltage Test 18. Check Memory time measurement test 19. Check Memory voltage measurement test 20. Self Test the relay if applicable


ITEM DESCRIPTION DONE REMARKS 1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. End to End test 5. On Load Test As per

5.23.3




S/S Name / No:………….. Bay No.: ………………….

2.17 Directional Negative Phase Sequence over current- 67Q






& 4.3 if applicable

2. Check relay applied configuration according to approved configuration and to schematic drawing.

3.

Adjust relay time setting as instantaneous zero seconds. Adjust the tester direction angle as forward direction. Check Pick-up & Drop off Values of the Current and voltage, for all phases and select type of fault for testing.

4. Check test results for operating pick up values according to simulated fault types as the following:-Single phase to earth fault: the injected current at which the protection will operate = 3 expected setting pick up current value. Phase to phase fault: the injected current at which the protection will operate = √3 (expected setting pick up current value). 3 phase fault the relay will not operate

5. Check the directional operating characteristic angle by injecting suitable value of voltage and 1.5 of operating pick up value of

current and start from angle =0 to 360. Check test results and characteristic for determination operating and blocking areas.

6. Check the VT MCB trip will block the directional element.Check blocking voltage for directionality.

7. Check Led's for MCB /VT failure or fuse failure

8. Check led's for faulted phase identification /phase selection



1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. On Load Test


ATTACHMENT # 15 CHECK LIST S/S Name / No.: ……………………. Bay No.: ……………..


2.18 Line & Cable Differential Protection (87L/87C)


ITEM DESCRIPTION DONE REMARKS1. General Visual Inspection As per 4.1



1. General electrical tests As per 4.2

& 4.3 if applicable

2. Check Measurements if applicable 3. Check Differential Protection 3.1 Check I –DIFF > pick up and drop off and its time 3.2 Check Under switch on condition if applicable 3.3 Check I –DIFF >> pick up and drop off and its time 3.4 BIAS CHARACTERISTIC TESTING (for digital relays) 3.5 Unrestrained Current Pick-up Test and its time 3.6 Check Inrush restrain current if applicable

3.6.1 2nd harmonic blocking test: Inject one phase current as an example (1A - 60 HZ and 0.22 A - 120 HZ) the relay will not trip because of second harmonic inrush block

3.6.2

Cross blocking test: Inject one phase current as an example ( 1A - 60 HZ and 0.22 A - 120 HZ) and another phase by (1A – 60 HZ) The relay will trip after the summation of time by cross blocking with 2nd harmonic

3.7 Check 5th harmonic test 4 Check Thermal over load protection

4.1 Check with memory

4.1.1 Check with memory without preload

a. Calculate the trip time for thermal relay b. Calculate the thermal alarm time (stage 88%)

4.1.2 Check with memory with preload

a. Calculate the trip time for thermal relay b. Calculate the thermal alarm time (stage 88%)

5. Check that the differential element blocking with communication failure

Capacitive charging current test procedure: a. Activate the VTS and set value for line susceptance. b. Applied voltage at the local relay with out current and read

from the relays the differential current and base current. c. Repeat the above steps with change the values of the

voltage and susceptance.


ATTACHMENT # 15 CHECK LIST S/S Name / No.: …………………… Bay No.: ……………..

PAGE NO. 127 OF 191



Current transformer supervision test procedure: a. Simulate CTS state at local relay by inject –ve sequence

current. b. Increase currents gradually till reach the setting. c. Check the block state of the relay and measure the block

time. d. Check the restrain state of the relay. e. Check the alarms appear at the relay at local & remote ends. f. Check the value of the relay operates (Is1CTS). g. Simulate CTS, then decrease currents gradually till the relay

reset CTS state h. Check the value of relay operates.

Repeat the above steps for remote end

6. Check Back Up Over Current Protection As per 4.12

7. Check there is +ve can be send from test socket while test plug inserting to block the relay in order to prevent wrong operation.


ITEM DESCRIPTION DONE REMARKS 1. Final Setting as per approved setting 2. Stability & Sensitivity Test by simulation of external and

internal faults

3. Function Test & Scheme Check As per 5.3 4. Final Trip Test As per 5.11 5. End to End test As per

5.17& 5.18

6. On Load Test As per 5.23.2



PAGE NO. 128 OF 191


2.19 Auto Re-closer function






4.3 if applicable

2.

Check the operation a. Simulate the digital Input as trip and CB closed. b. After the dead time, the re-closer signal will be generated

by the relay. c. Repeated tripping of the breaker will result in another

closing shot (depending on the setting for dead time and the setting for number of shots)

d. After the final closing of Circuit breaker, apply the trip and notice that the relay will be locked out without any issuance of re-closer command.

e. Repeat the test as stated above with different dead timings. f. Check the re-closer conditions and remove them one by one

and notice the status

3. Check dead times 4. Check reclaim time 5. Check close pulse duration 6. Check re-close signal 7. Check lockout function 8. Check frequent operation function 9. Check circuit breaker fail to close & alarm contact

10. Check Re-closer blocking depending on the readiness of the circuit breaker.


1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. End to End test



PAGE NO. 129 OF 191


2.20 Transformer Differential Protection relay (87T)



2. CT ratios, and matching CT selection is correct for TX type (Star or Delta) and for Vector Group




& 4.3 if applicable

2. Through current restrain/stability test. For all phases and all types of faults

3. Pick-up\drop off differential current Id> test (without zero sequence elimination and with it). For all phases and all types of faults and transformer sides.

4. Pick-up\drop off differential current Id>> test. For all phases and all types of faults and transformer sides.

5. BIAS CHARACTERISTIC TESTING for all phases and all types of faults

6. 2nd & 5th Harmonic restraint Test. For all phases and all types of faults

7. Cross blocking function test. For all phases and all types of faults 8. Negative sequence Relay Operating Angle test ( if it is applicable)

9. Sensitive negative sequence ( turn-to-turn fault ) test( if it is applicable)




faults As per

5.15 3. Function Test & Scheme Check As per 5.4 4. Final Trip Test As per

5.11 5. On Load Test As per

5.23.4



PAGE NO. 130 OF 191


2.21 Restricted Earth Fault (REF) Transformer Protection (64NP / 64NS)





1. General Electrical Test As per 4.2 &

4.3 if applicable

2. Check Pick-up \ drop-off voltage and corresponding current by injecting voltage for all available adjustable settings.

3. Non linear resistor (NLR) characteristic test.





faults As per 5.16

3. Function Test & Scheme Check As per 5.4 4. Final Trip Test As per 5.11 5. On Load Test As per

5.23.5



PAGE NO. 131 OF 191


2.22 Over/Under-Frequency & Frequency Rate of Change Protection (81/81R)




2.22.2 Over/Under Frequency Protection Relay Electrical tests ITEM DESCRIPTION DONE REMARKS


& 4.3 if applicable

2. Check f>, f< Pick up & drop off for all stages and for selected various adjusting setting values.

3. Check f>>, f<< Pick up & drop off for all stages and for selected various adjusting setting values.

4. Check time settings for all stages and for all frequency functions ( f<, f>, f>>&f<<)

5. Check frequency rate of change for all stages.df/dt 6. Check Blocking pickup and reset for Under voltage condition.

7. Check applied voltage with measured voltage on relay display screen if applicable (for digital relays).


1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.6 3. Final Trip Test As per

5.11



PAGE NO. 132 OF 191


2.23 Automatic Voltage Regulation & Control (90)







& 4.3 if applicable

2. Check the line drop compensation. 3. Regulating Value ∆U % Test. 4. Circulating current Test if applicable. 5. check of voltage levels

6. Check the effect of load shedding enable and the effect at various settings.

7. check of linear time delay 8. Check of inverse time delay. 9. Raise & Lower command time delay measurement. 10. Over and under voltage blocking test. 11. Over current blocking test.




1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.5 3. On Load Test



PAGE NO. 133 OF 191


2.24 Disturbance & Fault Recorders (DFR)




2. Check the DFR name plate information for compliance to approved drawings and equipment/ material list.



1. General Electrical Test As per 4.2

& 4.3 if applicable

2. MEASURE A/D REF. BETWEEN TERMINALS.

3. Ensure that the T/line parameters for DTF feature (if applicable) are available at site.

4. Check the communication channels from the DFR to the destination (printer, backup hard disk, PC workstation, other DFR, …etc)

5.

Check the configuration of the Disturbance Fault Recorder for following Input Channels as per allocation. (A) Analogue Input Channels

a. Current Channels b. Voltage Channels c. Frequency Channels

(B) Digital Input Channels Binary / ON-OFF input Channels.

6. Check the calibration of Analogue Input Channels

a. Off Set or Zero Adjustment b. Gain adjustment

7.

a. Trigger Test for input Channels one by one. i. Digital Input Channels one by one. ii. Analogue Input Channels (sensor trigger) Current Channel over Trigger Test at 110 % and 150%of

rated current and Final Trigger setting at 110% for Line currents and at 40% for Residual/ Neutral currents.

Voltage Channel under Trigger Test at 75% and 90% of rated voltage and Final trigger setting at 90%.

Frequency settings under & over trigger Test at 59.8 and 60.2 Hz respectively. Final trigger setting at 60.2 Hz.

Trigger By network from another DFR (cross trigger).).

8. Check the record of triggered inputs in the Disturbance Fault Recorder and compare.

9. Check different record types & Scales a. Continuous slow scan



PAGE NO. 134 OF 191



b. Fault / Disturbance Record 10. Check availability of spare channels for future extensions.


1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.33. Final Trip Test As per 5.11

4. End to End test As per

5.18, 5.17



PAGE NO. 135 OF 191


2.25 Sequence of Events Recorder (SOE)




2. Check the Sequence Of Event recorder name plate information for compliance to approved drawings and equipment/ material list.



1. General Electrical Test As per 4.2

& 4.3 if applicable

2. Check the communication channels from the S.E.R. to the destination (printer, backup hard disk, PC workstation, …etc)

3. Check the configuration of the S.E.R. for digital Input Channels as per allocation. (Binary / ON-OFF input Channels.)

4. Trigger Test for digital input Channels one by one. 5. Check the record of triggered inputs in the SER and compare. 6. Check availability of spare channels for future extensions.


ITEM DESCRIPTION DONE REMARKS1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.3 3. Final Trip Test As per 5.11 4. End to End test As per

5.18, 5.17



PAGE NO. 136 OF 191


2.26 Annunciator (alarm module)



2. Ensure that all Annunciation Modules are properly identified as per the approved drawings and relevant SEC standards and that the identification does not obscure information displays.

3. Check for the correct writings (litra) of alarms. 4. Check for the correct color coding for trip / non-trip alarms.

5. Check the total number of annunciator windows it should have a 10% spare provision for urgent and non-urgent alarms.




& 4.3 if applicable

2. Check the Lamp Test and confirm that all indications are lighted up.

3. Check all applied settings are according to approved settings in schematic drawings.

4.

Test all the alarms and check silence, acknowledge and reset functions. a. Alarm indication lamp flashes on receipt of alarm. b. Pressing Acknowledge does not reset the alarm. c. Alarm does not reset until Reset is pressed.

5. Check annunciator regulated alarm output voltage.

6. Check dual supply operation by disabling primary and back-up supplies one at a time, and check relay indication for supply healthy/fail.

7. Confirm the annunciator failure alarm to SCADA.


1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.10 3. Final Trip Test As per 5.11 4. End to End test As per

5.17, 5.18



PAGE NO. 137 OF 191


2.27 Transducers

2.27.1 Mechanical Checks And Visual Inspection


1. General visual inspection As per 4.1



2. Verify that the transducer output range is compatible with the RTU input setting.

WATT TRANSDUCER Inject the transducer with current and voltage at 20,50,75&100% rating varying the injection angle from 0,90,180,270º

1. Check the Input Watt and output Ratio error at Different Current and Voltage levels.

2. Check the Input Watt and output Ratio error at Different Power Factor values and Angles.

VAR TRANSDUCER Inject the transducer with current and voltage at 20,50,75&100% rating varying the injection angle from 0,90,180,270º

1. Check the Input VAR and output Ratio error at Different VARs.

2. Check the Input VAR and output Ratio error at Different Power Factor values and Angles.

VOLTAGE TRANSDUCER Inject the transducer with voltage at 20, 50, 75&100% rating.

1. Check the Input and output Ratio error at Different Voltage Values.

CURRENT TRANSDUCER Inject the transducer with current at 20, 50, 75&100% rating.

1. Check the Input and output Ratio error at Different Current Values.

FREQUENCY TRANSDUCER Inject the transducer with voltage with varying the frequency at 20, 50, 75&100% rating.

1. Check the Input Frequency and output Ratio error at Different Frequency Values.

2. Check input signal proportional to the output dc signal Test.

3. Check the connections according to manufacturer's standard connection procedure

WATT-HOURS TRANSDUCER



PAGE NO. 138 OF 191


Inject the transducer with current and voltage at 20,50,75&100% rating varying the injection angle from 0,90,180,270º For a duration of 15 minutes minimum.

1. Check the accuracy of watt-hour Meter. 2. Check the polarity of the potential transformer. 3. Check the polarity of the current transformer.

4. Check the connection of the potential and current circuit base on manufacturer’s standard procedure.

VAR-HOUR TRANSDUCER Inject the transducer with current and voltage at 20,50,75&100% rating varying the injection angle from 0,90,180,270º For a duration of 15 minutes minimum.

1. Check the accuracy of VAR-hour Meter 2. Check the polarity of the potential transformer 3. Check the polarity of the current transformer

4. Check the connection of the potential and current circuit base on manufacturer’s standard procedure



1. Final Setting as per approved setting



PAGE NO. 139 OF 191


2.28 ACSE / ABTS / TOP

Automated Bus Transfer Scheme (ABTS) Auto Changeover Switching Equipment (ACSE)

Trip on Parallel (TOP)

2.28.1 General Mechanical checks and visual inspection ITEM DESCRIPTION DONE REMARKS 1. General Visual Inspection As per 4.1

2. Check the communication channels like Profibus, Modbus, and Ethernet etc are working.




4.3 if applicable

2. Check the indications of PLC working OK. 3. Check the Schematic diagram for Automatic Control Schemes. 4. Check the different combinations of Schemes.

5.

Check the conditions for closing standby breaker (bus coupler or incomer)

a. Check Synchronizing between the Buses. b. Be sure all Circuit Breakers are in service and in Remote

Position. c. Be sure that all Potential Transformers are in service. d. All the Potential Transformers MCB's are ON. e. ABTS / ACSE are on and in service.

6.

Check the Blocking conditions of standby breaker (bus coupler or incomer) from closing during following conditions:

a. Sensitive Earth Fault operation. b. 132 KV or 110 KV or 13.8 KV Bus Bar Differential Relay

operations. c. ABTS off or out position. d. If Bus Section over Current works. e. Manual opening of CB f. Overload conditions: Transformer LV O/C or Transformer

winding temperature protection operated. g. Transformer high side time over current.

7. Prove scheme for opening of bus section breaker to break parallel of three transformers is functioning.

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

9.

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).




1. Final Setting as per approved setting 2. Function Test & Scheme Check As per 5.8

ATTACHMENT # 15 CHECK LIST S/S Name / No.: ……………………


Bay No.: ……………..





2. Check the communication channels like Profibus, Modbus, and Ethernet etc are working.




4.3 if applicable

2. Check that rating of the PLC of ACCS agrees with the Auxiliary Supply to which it is connected.

3. Manufacturer should be submitted ACCS configuration to SEC and approved.

4. Check PLC applied configuration according to approved configuration, schematic drawing and operation requirement.

5. Check the Schematic diagram for ACCS Schemes according to single line diagram and protection requirement.

6. Ensure that all ACCS setting can be changed from HMI of ACCS and the setting saved without changed if DC supply is switched off.

7. Perform PLC self-test procedure and external communications checks.

8. Ensure that the ACCS mimic diagram for panel and HMI are matching with actual switch gear panels and single line diagram of approved drawings.

9.


10. Check Automatic switching ON and OFF of the capacitor banks shall be based on 1- Reactive Power measurement 2- Voltage measurement on respective busses 3- Power Factor

11.

Check and measure setting of Over Voltage, Under Voltage, Leading power factor, Under MVAR, Over MVAR. And Verify For ACCS Secondary injection measurements by Injected Voltage and current and ensure that the error percentage between HMI reading and injected value for Voltage and reactive power and power factor with in the acceptable limit.

12. Check all interlock circuit and elapse times for capacitor are as per approved drawing and ACCS configuration and settings



PAGE NO. 142 OF 191



13.

Checking of the ACCS SCHEME: Check status of all related circuit breakers, devises, equipments and protective relays for each case. Check LEDs, display messages and alarm annunciations settings for each case. Ensure that all interlock circuit for capacitor is as per approved drawing and ACCS approved configuration. Measure all time settings in PLC configuration for all cases.


ITEM DESCRIPTION DONE REMARKS1. Final Setting as per approved setting2. Function Test & Scheme Check As per 5.9





3.0 CHECK LIST OF PROCEDURE FOR SCHEME AND FUNCTIONAL CHECKS

3.0 CHECK LIST OF PROCEDURE FOR SCHEME AND FUNCTIONAL CHECKS 141

3.1 General Panel Function Tests 142 3.2 Local Control Cubicle (LCC) Panel Function Test 144 3.3 Relay & Control Panel Function Test 146 3.4 Transformer Function Test 151 3.5 Automatic Voltage Control Panel Function Test 153 3.6 Load Shedding & Under Frequency Panel Function Test 154 3.7 Bus Bar Protection Panel Function Test 155 3.8 ACSE / ABTS / TOP Function Test 156 3.9 ACCS – Automatic Capacitor Control System 157 3.10 Common Alarms Panel Function Test and Alarm Scheme Test 159 3.11 Final Trip Test 160 3.12 Synchronizing Relay 161 3.13 Bus Bar Protection Stability & Sensitivity Test 163 3.14 Stuck Breaker Protection Stability & Sensitivity Test 165 3.15 Transformer Differential Protection Stability & Sensitivity Test 168 3.16 Restricted Earth Fault Protection Stability & Sensitivity Test 170 3.17 End To End Test for Over Head Line Feeders 171 3.18 End To End Test for Under Ground Cable Feeders 176 3.19 SCADA Point List checking 178 3.19.1 SCADA Commands Tests 178 3.19.2 SCADA Back Indication Tests 178

3.19.3 SCADA Alarms Tests 178 3.20 Metering and Readings through SCADA to ECC 179 3.21 Pre-Energization Confirmation Checks 180 3.22 During Energization Confirmation Checks 181 3.23 On Load Tests 183

3.23.1 On Load tests for CT/VT Circuits & Transformer Inspection. 183 3.23.2 On Load Line/Cable Differential Protection Stability & Sensitivity 183 3.23.3 On Load Confirmation of Relay Directionality 184

3.23.4 Transformer Differential Protection on Load Stability Tests 186 3.23.5 Restricted Earth Fault Protection on Load Stability Tests 186 3.23.6 Bus Bar Protection on Load Stability Tests 186 3.23.7 Stuck Breaker Protection On-Load Stability & Sensitivity Tests 187



3.1 General Panel Function Tests


1.

Before testing a. Approved commissioning copy schematic drawing shall be

pre-checked. b. All secondary injection and all components tests shall be

completed and witnessed. All test results must be available and signed.

c. Auxiliaries, timers, contactors, pulse units, annunciators, MCB’s … etc.

d. All final settings applied as appropriate (timers, pulse units, annunciators) shall be applied and witnessed.

2. 20% of all auxiliary relays, timers, contactors, pulse units, annunciators, MCB’s … etc, should be tested and witnessed.

3. Verify that each supply is wired point to point, with no unsupervised branches. Supervision is checked by wire removal at every point in the circuit to make sure the supervision flag drops.

4. Check that the ability to access to every equipment terminal is easy

5. Check DC source and DC loops (control, interlock & power supply) according to the schematic drawings.

6. Check DC Segregation for opening / tripping circuit, closing circuit, & alarm circuit.

7. Check AC and DC MCB's ratings grading. 8. Check the supply change over function. 9. Check AC source and AC loops. 10. Check the thermostat and the heaters.

11. Check the AC lamp,DC lamps and door switch and Check lamp test for all equipment

12. Check AC socket. 13. Check the ferrules as per specification. 14. Check the labels. 15. Check DC supervision. 16. Check AC supervision.

17. Check the alarm signal to SCADA, Mosaic panel (control panel), Alarm panel, Protection panel, fault recorder including equipment fail and watchdog alarms.

18. All control, protection, metering and signaling equipment shall be capable of satisfactory operation at an indoor ambient temperature of 55°C.

19. Check cable into control kiosk /cubicles/panels are properly sealed or glanded and terminated on suitable terminals in kiosk.

20. Check panels earthing as per specification. 21. Check cables for proper shielding and grounding

22.

Check proper Terminal Block arrangement and labeling: a. Shorting & Isolating for CT circuits b. Isolating for VT circuits c. Solid Type for control circuits





ITEM DESCRIPTION DONE REMARKS d. Trip Isolation facilities where needed

e. Solid type with spring loaded for trip circuits f. Knife type for alarms

23. Check that heat sources such as external resistors are covered with suitable covers and far away from panel wiring.

24. Check that CT and VT circuits are facilitated with suitable covers and caution labels for protection.

25. Ensure availability of proper test facility depending on the type of protection or metering equipment: Shorting test facility for current circuits Isolating test facility for voltage circuits Trip and Alarm isolation when relays are being tested

26. Check that caution labels and caution clauses in the schematic drawing are included to prevent accidental on-load opening of CT circuits.

27. Check the availability of proper panel lighting controlled by a door switch and electrically connected to the emergency DC supply as well.

28. Check Color coding of panel wiring as per relevant specification 29. Check that at least 10% spare cable cores are provided and

terminated at the terminal blocks farthest from the cable entry.

30. Check that percent (10%) spare terminals shall be provided on each terminal block.

31. Check that ten percent (10%) spare alarm windows are available for future modifications

32. Check that terminal blocks are grouped according to function, i.e. Power Supplies (AC or DC), VT, CT, DC controls, annunciation, SOE, SCADA etc. and shall be labeled accordingly. Terminal blocks for different voltages (AC or DC), CT, PT shall be located separated DIN rails.

33. Check that the physical wiring matches the schematic drawings and that any difference between scheme and implementation or correction in interface points is marked up in green and red ink.

34. Check wire rating, color coding, cross section, ferruling, trip markers ('T') and DC supply markers ('+' , '-')

35. Protective shrouds on high voltage areas in the panel such as CT terminal blocks with caution labels, protective shrouds on exposed resistors for high impedance protection relays, protective shrouds on metrosil's for REF … etc



Bay No.: ……………..

3.2 Local Control Cubicle (LCC) Panel Function Test

3.2.1 General Mechanical checks and visual inspection ITEM DESCRIPTION DONE REMARKS 1. General Visual Inspection As per 4.1

2. Panel condition, cleanliness, organization, labeling, readiness for service, panel doors, handles...etc



ITEM DESCRIPTION DONE REMARKS 1. General Function Tests As per 5.1

2.

Check proper arrangement and labeling of all bays and compartments in the mimic diagram on the LCC panel, and that these labels agree with the switchgear layout, the mimic panel in the control room and the approved drawings.

3. Check proper labeling and arrangement of gas and hydraulic diagrams on the LCC panel.

4.

If withdrawable circuit breakers are used for isolating purposes then indication of circuit breaker “service”, “test” and “withdrawable” positions shall be provided on the panel and connected to SCADA interface panel.

5. Check All panel alarms, initiated from the main source (contact of gauge, breaker...etc) to all destinations (control room , common alarm panel, LCC Annunciator , SCADA)

6. Make sure that all mechanism compartments are easily accessible and properly arranged for future maintenance or inspection.

7.

Check local (Switchgear mechanism compartment and LCC panel) and remote (control room and SCADA back indication) equipment position indication of all switchgear, including half way position indication at test and service positions according to approved schematic drawings..

8. Check the flickering indication of DS/ES during moving including half way position indication at test and service positions according to approved schematic drawings.

Operation 9. Check the function of circuit breakers ( open – close – trip1 – trip2)

10.

Check CB Anti Pumping Function / Trip Free Function at local and remote position) and ( at test and service position) Step 1: Ensure Gas, Air and DC Supply is normal for the CB under

test. Step 2: Close the Breaker Electrically and Hold the Control Switch

in Switch in ‘CLOSE’ position.

Local & remote1






Step 3: Trip the Breaker by Externally extending the DC Supply to Trip Circuit. (Not by any trip relays which is used for close interlock)

Step 4: Observe the Breaker to ‘TRIP’ and remain in ‘OPEN’ position & does not close.

Step 5: Thus Anti Pumping function found working with the above sequence.

11. Check CB Anti-Slam Function

12. Check the function of lock switch and emergency switch of each component according to schematic drawing.

13. Check the function of the isolators and earth switches ( open – close)

Local & remote

14. Check local and remote (from control room & SCADA) operation of CB, DS, ES.

15. Check the all auxiliary contacts (52-a /52-b) of the circuit breaker and the DS / ES

16. Check breaker closing/ tripping blocking e.g. for SF6 low stage 1/ stage 2

INTERLOCKING

17. Check that the interlocking schedules are approved and revised by operation department.

18. Checks the interlock circuit compared with the approved drawing and ensure also that there are interlock between mechanical and electrical operation.

19.

Check that the interlock circuit is normally blocking even with DC failure. In the design of the scheme continuously energized relays shall be avoided as far as possible. It shall operate in a “fail-safe” mode by ensuring that interlock release conditions are established only by energizing a relay or relays.

20. Ensure that lockable switch is provided at each local control kiosk to manually over-ride the interlocking for that switchgear bay.

21. Ensure that Manual operation of all earthing switches and maintenance earthing devices is only possible under electrical interlock release conditions.

22. Check operation blocking during half way position or disconnector / earth switch failure.

23. For withdraw-able circuit breakers check mechanical interlocking between earth switches and breaker rack-in rack-out operation.

24. Check mechanical interlocking conditions as per approved interlock diagram.

25. Check proper operation of de-interlocking selector switch and ASSURE the lock ability of this selector if available.

26. Check CB Close block conditions for example permanent faults (lockout operated) or GIS malfunction (insulation medium low).



3.3 Relay & Control Panel Function Test



2. Panel condition, cleanliness, organization, labeling, readiness for service, panel doors, handles...etc




1. General Electrical Tests for Protection Relays As per 4.2 &

4.3 2. General Function Tests As per 5.1

3.

Trip circuit supervision Verify integrity of individual trip circuit supervision, including pre-closing and closed CB supervision. Make sure wiring is made point to point with no branched connections to make sure that all trip supplies are supervised Disable Trip circuits individually and verify that the other circuit is healthy and operable. Trip circuit supervision should have indication on both the control panel and in the alarm scheme

4.

Verify tripping arrangement as per approved schematic drawings, example:

a. First main protection to trip on circuit 1 b. Second main to trip on circuit 2 c. Bus bar protection or breaker fail or Transformer differential

protection to trip on both TC1 and TC2

5.

Check wiring for bus bar protection loop and CBF relay, check CBF supply is ok, check CBF initiation from all trip relays, and that all trips (even mechanical trips) initiate trip relays, which then initiate the CBF.

6.

When specified, the relay panel should incorporate proper In/out facility: Locally or remotely operated (SCADA) Indication and or Alarm of the status of the protection (in or out) Disconnecting alarm and trip contacts when in out position Bus-bar zone out of service will still trip depending on check zone (for discrimination zone out), or depending on discrimination zone (for check zone out of service)

7. Verify the use of close blocking lockout relays and auto resetting trip relays is as per scheme depending on the type of protection operated.

8. Mimic & Indication



PAGE NO. 149 OF 191



Verify that the mimic diagram and equipment labeling is correct and matches the switchgear layout, the LCC panel, and the approved drawings. Verify that the indication in the mimic panel matches the indication in the LCC panel and the actual - position of CB/DS/ES is it open, closed, moving (flickering), or middle position (flickering). Availability and operation of lamp test switches

9.

Local Remote Operation Check the discrepancy switches for proper operating (open, close) and check their contacts arrangements to match the schematic drawings for number of contacts and type of contact (NO, NC) Check the availability of lockable local/remote switches and check local and remote commands of the switch gear from the control panel and SCADA and ensure that the electrical interlocking is maintained for remote operation of the switchgear from the mimic/control panel. Check all operating loop contacts/conditions for SCADA commands individually including necessary interlocks, SF6 low, close block, …etc Check commands and back indication with SCADA interfacing panel.

10.

Metering

Check that meters are available in the correct scales for the rating of the equipment and that they have been tested and final set (for digital equipment) correctly and are properly labeled. Check availability of proper test facility for testing of panel meters, this facility MUST have proper polarity wiring for accurate testing.

11.

Synchronizing panel:

Verify the required conditions to connect the voltage transformers of selected feeder to the Synchro-check system Verify synchronizing interlock such as: Following selection of synchronize operation on the feeder, selection on any other feeders shall be prevented until the system has reset. MCB trip for the required P.T shall prevent synchronizing system operation Verify C.B closing with automatic synchronizing from local and SCADA, also check manual synchronizing Check the function of the bypass selector switch from SCADA and local. Check operation of indication & alarm lamps.

12. Check that alarm and also a visual indication shall appear on the substation central signaling system and the signal shall also be



PAGE NO. 150 OF 191



wired with a potential free N.O. contact to the SCADA interface cubicle for transmission to LDC.

13. Check that alarm system failure contacts initiates alarm to SCADA

14.

Check that all substation support systems (communication equipment, battery room MCB's, Battery chargers, Fire protection, HVAC control panel…etc) are incorporated in the substation general alarm scheme.

15.

Check that successful AC or DC automated bus transfer does not initiate any AC or DC supply fail alarms (that AC and DC fail alarms are non latching and that annunciator time setting is compatible with ATS change over settings).

16. Check proper time and color setting for alarms (trip and non trip / urgent and non-urgent) as per alarms specification.

17. Check zone selection for BB protection loop depending on isolator position.

18. Bus bar trips and trip conditions (by simulation from the source panel (bus bar panel)

3.3.3 Electrical test for numerical control relays panels.



2. Devices that have multiple standards of characteristics to be tested as per SEC used standards (example IEEE standard curves for Over-Current Time Inverse characteristics)


4.








PAGE NO. 151 OF 191



9.












20. Mimic and single line diagram on the relay display has to be checked according to approved single line diagram of SS

21. Control configuration and all functions of the relay have to be checked according to approved schematic diagram and approved configuration.

22. Interlocking logics have to checked and studied according to approved scheme and conditions.

23.

Check of all breaker, disconnector and earth switch positions. The position indications are checked by local operation in the field and the physical position of every device has to be compared with the shown position on the local mimic, the displays of the relays and on the SAS.

24.

Check of all breaker, disconnector and earth switch commands. The command have to be checked for the possible modes (Local, Emergency & Remote). Local operation mode at the relay display can be selected by selector button on the relay display. Every switching devices has to be operated (open and close) in the local mode. Remote mode at SAS at the relay display can be selected by selector button on the relay display. Every switching devices has to be operated (open and close) in the remote mode.





ITEM DESCRIPTION DONE REMARKS 25. The proper LED indication has to be checked.

26.

The interlocking logic for local and remote operation can be either checked from locally from relay display or remotely from SAS. These conditions have to be checked according to the approved base design document. Eventually the system contains an interlocking override function which has to be checked by the certain instance (e.g. Mimic, UBC or SAS. )

27. Checking of close blocking by lock out relay. 28. Checking of synchrocheck function. 29. Check of measurement. 30. Check of automatic voltage regulator. 31. Check of alarm panel. Remark: Substation automation procedures must be submitted from suppliers at least 6 months

before starting commissioning for study by SEC.



Bay No.: ……………..

3.4 Transformer Function Test

3.4.1 Transformer Relay & Control Panel Function Test

a. General Mechanical checks and visual inspection ITEM DESCRIPTION DONE REMARKS 1. General Visual Inspection As per 4.1

b. Electrical tests


A General checks

1. General Function Tests As per 5.1 2. Relay & Control Panel Function Tests As per 5.3

B Protection Panel Check

1. Verify the distribution of main and backup protections on the protection supplies( R1,R2,R3,R4)

2.

Verify that the Mechanical protection tripping by simulation from the source contact for EVERY mechanical protection from the source (from the protection device itself, not from the GTMK panel and not from the TX panel).

C Control Panel Check

1. Mimic has to be ok, color coding for HV, MV, and tertiary if applicable for single line should be correct.

2. Check interlocking between isolators and breakers and between HV and MV breakers (test / service conditions)

D Fire Protection Panel Check

1. DC supply and supervision for supplies shared between the relay panel and the fire protection control panel.

2.

Verify proper interfacing between fire protection scheme and transformer protection scheme: Trip both sides of the transformer Disconnect Transformer cooling fan motors Initiate water spray system in the Transformer Room

3.

Assure the connection fire protection alarm scheme to the substation alarm scheme for fire protection ready, healthy, operated, water low …etc Ensure that alarms are received at the Transformer control panel annunciator and reaching to SCADA.





3.4.2 Transformer Marshalling Kiosk (GTMK) function test




b. Electrical tests

ITEM DESCRIPTION DONE REMARKS 1. General Function Tests As per 5.1

2. Check the operation of Fans automatic, manual, local and remote positions.

3. Verify trip commands for transformer mechanical protection relays (Buchholz relay, Over Temperature protection, etc)

4. Check the supply changeover for fan motor circuit during: AC MCB trip Main source failure (under-voltage condition)

5. Ensure that spare CT cores for bushing CT's and NER CT are wired to the GT-MK panel and shorted and earthed using proper short/isolate facility



Bay No.: ……………..

3.5 Automatic Voltage Control Panel Function Test


ITEM DESCRIPTION DONE REMARKS1. General Visual Inspection As per 4.1



1. General Function Tests As per 5.1 ,

5.2

2. Ensure that all standard electrical tests of PT that feeds AVR by voltage signal are done.

3. Ensure that all standard electrical tests of CT that feeds AVR by voltage signal are done (if CT applicable).

4. Ensure that the phase sequence of voltage which starts from PT secondary to AVR is correct.

5. Ensure that the phase sequence of current which starts from CT secondary to AVR is correct (if CT applicable).

6. Check that the Remote Tap Position Indicator matches the indication on the Local Tap Position Indicator and the indication sent to SCADA

7. Check local operation interlocking for Raise & Lower commands depending on Local / Remote and Auto / Manual Selector switches.

8. Check remote operation interlocking for Raise & Lower commands depending on Local / Remote and Auto / Manual Selector switches.

9. Check that Raise & Lower commands to the tap changer are blocked during tap changer operation for manual commands and that AVC delay time setting is greater than tap changer step time.

10. Check panel indication for tap change in progress

11. Ensure that all OLTC alarms are wired to the AVC panel and incorporated in the alarm scheme (to SCADA) (OLTC AC / DC fail, tap changer out of step, OLTC Buchholz, etc)

12. If applicable, check remote operation of transformer fans.

13. Check the operation of load shedding (if applicable) from SCADA.

14. Check SCADA control and back indication of Auto/Manual voltage control scheme.

15. Check master / follower scheme if applicable.




Bay No.: ……………..

3.6 Load Shedding & Under Frequency Panel Function Test







5.2 2. Check the trip matrix of the frequency relay for each stage.

3. Check the trip matrix of the under-voltage relay for each stage (if applicable)

4. Check the Voltage Change over Scheme.




3.7 Bus Bar Protection Panel Function Test


ITEM DESCRIPTION DONE REMARKS1 General Visual Inspection As per 4.1




5.2

2.

Verify the CT switching scheme and proper zone selection if hardwired. For digital protection schemes, verify the relay’s internal bus-bar replica and zone selection is correct including bus merge / load transfer conditions.

3. Check Bus-bar trip logic / conditions from the relay up to the circuit breakers

4. Test In / Out operation for each check zone & discrimination zone

5.

Test trip logic for each zone out: Discrimination zone out = 1 out of 1 tripping based on check zone operation. Check zone out = 1 out of 1 tripping based on discrimination zone operation. Both CZ and DZ out = no tripping for that bus zone.

6. CBF supply and supply supervision if supplied through the Bus-bar panels.

7. Check CBF relay tripping through bus-bar panel bus replica scheme.




3.8 ACSE / ABTS / TOP Function Test

Auto Changeover Switching Equipment, Automated Bus Transfer Scheme, Trip on Parallel Scheme






1. General Function Tests

As per 5.1 , 5.2

2. Study the different schemes for automatic closing of the standby or the parallel running Transformer incomer Breakers or Bus section in case of tripping of any transformer available in the Schematic diagram,

3. Study test format compared with schematic drawing and protection requirement.

4. Check status of all related circuit breakers, devises, equipments and protective relays for each simulation case.

5. Check 4 out of 5 interlocking scheme is achieved while DC loss of PLC device.

6. Simulate operation cases one by one according to test format and record results. (Check the Schemes by tripping of the different transformers one by one and changeover of the switchgears are according to the Scheme.) Check the blocking of Changeover for the Blocking Conditions of Auto Changeover of Switchgears. Check the Scheme opening of Bus Couplers or Incomers in case of energization of tripped Transformer.

7. Check LEDs, display messages and alarm annunciations for each simulation case.

8. Check all cases and conditions at ACSE/ABTS ON and ACSE/ABTS OFF positions. And check all cases and conditions at TOP ON and TOP OFF positions.

9. Check all cases and conditions at control mode and ECC mode and segregation between each other.

10. Measure all time settings in PLC configuration. 11. Check panel indication for:

ACSE/ABTS ready ACSE/ABTS close command failed TOP scheme selected



PAGE NO. 159 OF 191




ITEM DESCRIPTION DONE REMARKS 1 General Visual Inspection As per 4.1

2 Check current transformer circuits and voltage transformer circuit are connected to the ACCS correctly as per approved drawing.



1 General Function Tests As per 5.1 ,

5.2

2 Check all related CT's, VT's, circuit breakers, auxiliary relays, protection relays and metering devises were tested.

3 Check that rating of the PLC of ACCS agrees with the Auxiliary Supply to which it is connected.

4 Manufacturer should be submitted ACCS configuration to SEC and approved.

5 Check PLC applied configuration according to approved configuration, schematic drawing and operation requirement.

6 Check the Schematic diagram for ACCS Schemes according to single line diagram and protection requirement.

7 Ensure that all ACCS setting can be changed from HMI of ACCS and the setting saved without changed if DC supply is switched off.

8 Perform PLC self-test procedure and external communications checks.

9 Ensure that the ACCS mimic diagram for panel and HMI are matching with actual switch gear panels and single line diagram of approved drawings.

10


11 Check of test and measuring instruments calibration certificates.

12

Verify For ACCS Secondary injection measurements by Injected Voltage and current and ensure that the error percentage between HMI reading and injected value for Voltage and reactive power and power factor with in the acceptable limit.

13

Automatic switching ON and OFF of the capacitor banks shall be based on 1- Reactive Power measurement 2- Voltage measurement on respective busses 3- Power Factor

14 The testing should be done sequentially using the proceeding tables with all the preliminary settings. Using a 3 phase injectors for



PAGE NO. 160 OF 191



voltage, current and power factor for each transformer, each case and mode of operation should be simulated and verified according to the setting.

15

The Common operational mode like Over Voltage, Under Voltage, Leading power factor, Under MVAR, Over MVAR should be Simulated in each cases above at ON position and OFF position and TEST position.

16

The Common operational mode like Over Voltage, Under Voltage, Leading power factor, Under MVAR, Over MVAR should be Simulated in each cases above at LOCAL position and SCADA position.

17

The Common operational mode like Over Voltage, Under Voltage, Leading power factor, Under MVAR, Over MVAR should be Simulated in each cases above at AUTO position and MANUAL position.

18 Ensure that all interlock circuit and elapse times for capacitor are worked properly as per approved drawing and ACCS configuration and settings.

19

Checking of the ACCS SCHEME: Check status of all related circuit breakers, devises, equipments and protective relays for each simulation case. Check LEDs, display messages and alarm annunciations for each simulation case. Simulate operation cases according to test format and record results. Ensure that all interlock circuit for capacitor is worked properly as per approved drawing and ACCS configuration. Measure all time settings in PLC configuration for all above cases.





3.10 Common Alarms Panel Function Test and Alarm Scheme Test






5.2

2. Study the schematic diagrams for alarm showing auxiliary contacts for operation of different equipments, relays or breakers.

3. Generate the alarms by removing wire or bypass (making jumper) the NC or NO contacts from the alarm source.

4. Check the alarms in the S.E.R. outputs, annunciation panel and the SCADA system at Remote Terminal Unit are in the same sequence as generated.

5. Check the alarm wording in the S.E.R. outputs, annunciation panel and the SCADA system at Remote Terminal Unit are correct and understandable.

6. Check the outputs on the resetting of alarms.

7. Check alarm scheme supply changeover

8. Check the alarm scheme for proper initiation of the common buzzer or horn from all connected annunciators in the control room.

9. Check alarm failure contacts to SCADA

10. Check alarm windows for labeling, colors, and time delay settings for trip/non-trip alarms

11. Check that any alarm 'sleep mode' selector switches are lockable type switches and check their operation.

12. Check lamp test facilities and silence, acknowledge and reset buttons for proper operation.



3.11 Final Trip Test


1. Perform Tripping of Power Transformer Controlling Breakers through test contact of Buchholz Relay, OLTC Protective relay, Oil & Winding temperature protection.

2. Perform Tripping of Power Transformer Controlling Breakers through each Electrical Protection by closing tripping contacts through secondary injection on the protection relays above the final setting.

3. Perform Tripping of Shunt reactor Controlling Breakers through test contact of Buchholz Relay, OLTC Protective relay, Oil & Winding temperature protection.

4. Perform Tripping of Shunt reactor Controlling Breakers through each Electrical Protection by closing tripping contacts.

5. Perform Tripping of Capacitor Bank Controlling Breakers through each Electrical Protection by closing tripping contacts.

6. Perform Tripping & Inter-Tripping of Controlling breakers of Feeders/Transmission lines through each protection installed by closing tripping contact through secondary injection on the protection relays above the final setting.

7. Perform Tripping of Controlling Breakers of Bus Bar Schemes through Bus Bar Differential Protection by closing tripping contact of the relay through secondary injection on the protection relays.

8. Perform Tripping & Inter –Tripping for Breaker Failures schemes through secondary injection on the CBF relay with simulated initiation from the source contact on every protection relay.

9. Perform Tripping of Bus Coupler/Sectionalizer by closing trip contacts of the relays installed through secondary injection on the protection relays.

10. Ensure that every protection operated (during secondary injection trip test) initiates CBF scheme and check indication & alarms.

11. Ensure that every protection trips through its desired trip circuit independently by disabling the other trip circuit before secondary injection.

12. Ensure that every protection operated (during secondary injection trip test) initiates FR and check FR massage.

13. For OHL /UGC protection ensure that every protection operated (during secondary injection trip test) initiates inter trip sending relay and check indication & alarms.

14. For OHL protections ensure that fast trip protection start A/R and delayed trip blocked A/R and check indication & alarms.

15. Ensure that both trip circuits are normalized at the end of the trip test.




Bay No.: ……………..

3.12 Synchronizing Scheme Check


1. CAUTION: remove all VT's terminals from VT terminal block in VT's boxes and separate all VT's terminals from VT loops. Assure that all VT's impossible to be fed back from secondary sides.

2. Check that all voltage transformers were tested. 3. Check that VT loop test were done. 4. Check VT data and voltage rating, and check MCB's rating. 5. a. Check VT's disconnectors opening alarms and their closing

condition in CB closing circuit. b. Check that positions of MCB's which exactly supply the

synchronizing scheme are included in CB's closing circuits.(according to scheme)

c. Check the line voltage loop by applying voltage from VT secondary terminal block of all bays one by one according to schematic drawing.

d. Measure voltage for all points in the loop. Check the switching points of any switch included in the loop at the close and open position. Check any relay contact included in the loop at the close and open status. Measure line voltage and bus voltage at synchronizing relays and read measurement values on relays displays and assure that there is line voltage only. Measure line and bus voltages at the synchronizing meters in synchronizing panels and assure that there is line voltage only.

e. Check that the only selected feeder for check its synchronization feeds line voltage to synchronizing meters panel.


7. a. Check VT's disconnectors opening alarms and their closing condition in CB closing circuit.


c. Check the bus voltage loop by applying voltage from VT secondary terminal block of all buses one by one according to schematic drawing. The status of bus coupler and bus section must be considered and synchronizing condition dependent on their positions must be studded and checked well.

d. Measure voltage for all points in the loop. Check the switching points of any switch included in the loop at the close and open position. Check any relay contact included in the loop at the close and open status. Measure line voltage and bus voltage at synchronizing relays and read measurement values on relays displays and assure that there is bus voltage only. Measure line and bus voltages at the synchronizing meters in synchronizing panels and assure that there is



PAGE NO. 164 OF 191



Bus voltage only. e. Check that only one voltage feeding synchronizing loop if the

two bus disconnectors connected to tow bus bars ( load transfer)


9. Check the dead line dead bus condition for all bays. Try to close CB's of all bays in all possible conditions (test and service positions) from local and ECC.

10. Check the live bus dead line condition for all bays Try to close CB's of all bays in all possible conditions (test and service positions) from local and ECC.

11. Check the live line dead bus condition for all bays. Try to close CB's of all bays in all possible conditions (test and service positions) from local and ECC.

12. Check the live line live bus condition or all bays. Try to close CB's of all bays in all possible conditions (test and service positions) from local and ECC.

13. Check the synchronizing condition for automatic recloser scheme if applicable.



PAGE NO. 165 OF 191


3.13 Bus Bar Protection Stability & Sensitivity Test


1.

The following activities should be completed before start the bus bar stability test

a. Secondary injection for bus bar protection relays b. Final Settings Applied for the bus bar protection relays. c. Function Tests and scheme check for Relay and Control Panels

(for proper command and indications). d. Function Tests and scheme check in GIS (for proper operation

of the breaker) e. Proper Operation of Bus-bar Protection and Circuit Breaker Fail

schemes f. CT loop test, CT primary Injection & Single earthing point

checked. g. Confirm that the single earthing point at the relay panel. h. Confirm that all associated CT cores are having the same Knee

point nearly. i. Check that all circuit breakers which needed to close loop are

closed according to single line diagram.


3. Caution: Any CT cores not related to bus-bar protection should be shorted for safety.

4. Caution: During sensitivity test the CT supervision relay may operate, the test plug should be putted in its test socket to prevent CT shorting during the testing and measuring currents.

5. Caution: The injected current should not exceed the smallest turns ratio CT.

6. Caution: Check that all safety precautions from electric hazard was taken as surrounding the testing area by caution tap, … etc.

7.

Inject primary current (5% of rated current) and Measure currents and their angles in BBP current circuit of the two bays which is under test (in LCC, BBP discrimination zone panels according to BB disconnector which is connected & check zone panel). Compare between currents and angles values to achieve stability. Measure the voltage across (CT supervision relays – differential relays – resistors – metrosil) for high impedance BBP or check measurement readings for low impedance digital relays.

8. Check stabilizing current Is and differential current Id values in digital differential relays Differential current Id should be zero.

9.

For sensitivity test, reverse the CT polarity of one bay and measure currents & their angles in BBP current circuit of the two bays which is under test (in LCC, BBP discrimination zone panels according to BB disconnector which is connected & check zone panel). Before injecting the current the cautions must be considered. Measure the voltage across (CT supervision relays – differential relays – resistors – metrosil) for high impedance BBP. Check the proper bus bar zone which shall be operated



PAGE NO. 166 OF 191



10. For sensitivity test, reverse the CT polarity and check stabilizing current Is and differential current Id values in digital relays. Check the proper bus bar zone which shall be operated.

11. Repeat the previous steps with another bus bar disconnector is closed for reference and test feeders

12. Repeat the previous steps with load transfer and keeping the two bus bar disconnectors are closed as a preference condition and check which BB zone shall operate.

13. Repeat the above steps for all phases.


15. Repeat the test for all feeders (holding one feeder as a reference for each test)



PAGE NO. 167 OF 191


3.14 Stuck Breaker Protection Stability & Sensitivity Test



2. The CT loop test, CT primary Injection & Single earthing point checked activities should be completed before start the stuck breaker stability & sensitivity test.

3. Verify that CT ratios for all CT’s used in the current summation scheme are matching for proper operation of the relay.

4. Check for proper shorting facility after the summation point of all CT’s

5. Check that the acceptance test and final setting for this relay have already been completed with satisfactory results. Check that all CT's were tested.


7. Check the time grading of operation between the feeder O/C+E/F relays, the stuck breaker protection, and the transformer incomer LV O/C +E/F relays.

8. Verify proper application of single earthing point in relay panel


ITEM DESCRIPTION DONE REMARKS1. General Function Tests As per 5.1


3. Caution: Any CT cores not related to stuck breaker protection should be shorted for safety.

4. All associated circuit breakers should be closed in service position.

5. You may have to test each protection element (O/C or E/F) independently depending on the setup of primary injection.

6.

Stability through simulation of external fault: Starting with a small primary current (5% of rated current). Inject primary current on the Bus-bar through a path energizing two of the CT’s used in the stuck breaker scheme and simulating an external fault. Verify with a clamp ammeter or a phase angle meter that the CT secondary currents are correct depending on CT ratio. Verify with a clamp ammeter that the summation current of both CT secondary circuits is 0mA. Verify the reading on the relay for 0A primary current.



PAGE NO. 168 OF 191



Increase the current injection gradually until you exceed the setting of the relay, the relay should not operate and the current summation readings shall remain 0mA. Repeat the stability test for other phases Using once of the CT’s used in the previous test as a reference, repeat the stability test for other CT’s by changing the path of primary injection to energize those CT’s and taking the stability measurements to verify the CT polarity, secondary ratio and secondary wiring is correct.

7.

Sensitivity test through simulation of internal fault: Choosing one CT as a reference (incomer or bus-section), reverse the polarity of the other CT (bus-section or incomer respectively), using external jumpers of suitable current rating and the isolating facility of the short-isolate terminal block for that CT. Starting with a small primary current < 50A. Inject primary current on the Bus-bar through a path energizing two of the CT’s used in the stuck breaker scheme and simulating an external fault. Verify with a clamp ammeter or a phase angle meter that the CT secondary currents are correct depending on CT ratio. Verify with a clamp ammeter that the summation current of both CT secondary circuits is double the secondary current of each individual CT and that the summation is correct. Verify the reading on the relay for 100A primary current (or double the injected primary current). Increase the current injection gradually until you exceed 50% of the setting of the relay, summation readings shall increase gradually until the relay picks up. Once the relay picks up, stop increasing the primary injection and record the exact pickup current of the relay in primary and secondary currents. After the preset time delay the relay should operate. Ensure the operation of all trip / lockout relays. Ensure the tripping of all associated circuit breakers. Ensure the proper initiation of panel indication or alarms as per the scheme. Repeat the sensitivity test for other phases. Using once of the CT’s used in the previous test as a reference, repeat the sensitivity test for other CT’s by changing the path of primary injection to energize those CT’s and taking the stability measurements to verify the CT polarity, secondary ratio and secondary wiring is correct.







9. Make sure that any protection elements that were disabled during the test have been brought back into service (Earth fault).

10. Ensure that all shorted CT’s cores are normalized.

11. Ensure that all shorted high impedance protections such as transformer REF are normalized.



3.15 Transformer Differential Protection Stability & Sensitivity Test

3.15.1 General Mechanical checks and visual inspection ITEM DESCRIPTION DONE REMARKS 1 General Visual Inspection As per 4.1

3.15.2 Electrical Checks


1. CT loop and primary injection tests should be completed for High voltage and Low voltage sides.


3. The final settings must be applied and tested before the stability test.

4. Check that all associated CT cores are having the same Knee point nearly for high voltage side and low voltage sides for high impedance protection.


6. Caution: Any CT cores not related to the transformer protection should be shorted for safety.

7. Check that Transformer is short-circuited at the LV side after the transformer LV Side CT for differential protection.

8. Isolate the Differential Protection Trip Links

9.

Before the test & switch on the 3 phase power supply: Check the balance and phase sequence of the three phases power supply at the HV side of the transformer. Switch on the power supply and check phase sequence and voltage values.

10.

Measure primary current of transformer HV &LV sides and compare with the expected calculated values. The phase angle between primary and secondary current for each phase depending on the transformer vector group.

11.

Stability: Measure (Primary current – secondary current – phase angles) for HV and low LV side. Read the differential operating and restrain Currents, the differential should be 0A

12.

Sensitivity: Reverse the polarity of CT for any side (HV or LV), by reversing that CT secondary wire. Measure and read primary, secondary, differential operating and restrain currents and phase angles. If the differential current is high enough, check the relay indication for pickup and trip.



PAGE NO. 171 OF 191



13. Normalize the reversed CT and repeat the test for other phases. 14. Normalize the trip isolation links. 15. Normalize the shorted CT cores.



PAGE NO. 172 OF 191


3.16 Restricted Earth Fault Protection Stability & Sensitivity Test


REMARKS DONE DESCRIPTION ITEM 1. Check the correct terminal connections. 2. Make sure there is no more than one earthing point on the

CT at the secondary circuit for HV side and LV sides. 3. Check that all associated CT cores are having the same

Knee point nearly. 4. IMPORTANT:-

Remove the neutral earthing resistor (NER) bypassing it to increase the current to facilitate measuring.

5. Holding the neutral CT4 as a reference: Apply single phase voltage on each phase (Red, Yellow, and Blue) individually. Stability:

Measure secondary current and its angle for the phase CT and neutral CT and check the values to decide the stability. Check the differential current and verify that it is zero. Measure the voltage across REF terminals and it is must be approximately 0 V.

6. If the relay operates wrongly in the previous case, ensure that there is no saturation in any of the CT's or any wrong circuit connection, or different CT ratios.

7. Sensitivity:

Caution: REF is a high impedance protection and should be tested as a trip/no trip test with short durations of power supply switching ON to protect the relay from burning. Isolate the trip link for REF protection. Cross the wiring for the phase CT (holding the neutral CT connection as a reference) Measure secondary current and its angle for the phase CT and neutral CT Check the differential current and verify that it is the summation of the two secondary currents. Check the REF terminal voltage with a voltmeter. If the measured voltage is greater than the final setting, normalize the trip link and observe the breaker tripping.

8. Repeat the test for the other phases (Yellow, Blue) 9. Normalize the CT connections.

Normalize trip isolation links 10.



PAGE NO. 173 OF 191


3.17 End To End Test for Over Head Line Feeders

3.17.1 Distance Protection ITEM DESCRIPTION DONE Remarks

1.

The following activities should be completed before start the end to end test

a. Secondary injection for main relays (Distance, Directional Earth Fault, and Over-Current).

b. Final Settings Applied for the main relays. c. Function Tests for Relay and Control Panels (for proper command

and indications). d. Function Tests in GIS (for proper operation of the breaker) e. Fault & Event Recorders commissioned and properly interfaced. f. Proper Operation of Bus-bar Protection and Circuit Breaker Fail

schemes g. Communication system tests.

2.


3.

Check functions and alarms of each communication channels individually by simulation these functions alarms in communication panel and check functions and alarms in remote end communication panel Check segregation between functions and alarms and channels.The communication channels with smallest prolonging time value are used for distance communication scheme and another for inter-tripping send and receive.

4.

POTT ( permissive over reach transfer trip) a. Simulate Z1 fault and measure time of z1 trip output contact and

check output of carrier send signal is obtained and check indication and alarm output contact.

b. Check the other zones operate without carrier send signal. c. Simulate carrier receive and check that the relay trip only during

z1 with its time and check tripping during extended zone with extended zone time plus receiving communication time.

d. Check if extended zone fault without CR, trip with Z2 time and CS to the remote end.

e. Check if all zones except extended zone the relay tripping results without release from the opposite line end (carrier receive), allowing the protection to function with the usual grading characteristic independent of signal transmission.

f. Check that the POTT is for forward direction only. g. Check all indications and alarm output contacts. h. Check communication fail condition according to the relay logic

scheme tripping with basic scheme.



PAGE NO. 174 OF 191


ITEM DESCRIPTION DONE Remarks

5.

PUTT ( permissive under reach transfer trip) a. Simulate Z1 fault and measure time of Z1 trip output contact and

check output of carrier send signal CS is obtained and check indication and alarm output contacts.

b. Check that only Z1 transmit CS and the other zones and extension zone operate without carrier send signal.

c. Check if extended zone fault with CR , trip with extended zone time plus receiving communication time and without

6.

Blocking scheme a. Check if the forward zones fault without blocking signal receives

from remote end, aided trip with aided trip time and no CS to remote end.

b. Check if the forward zones fault with blocking signal receives from remote end, trip with zones delay time according to final setting and no CS to remote end.

c. Check if the reverse zone fault, trip with reverse zone time and CS to remote end.

d. Check if communication channels fail the relay operates with basic scheme.

7.

Week in feed function a. echo only

i. Check if C.B off & carrier receive the Echo signal send immediately.

ii. Check if C.B. on & carrier receive the Echo signal send after time delay (according to setting).

b. echo and trip i. Check if C.B off & carrier receive the Echo signal send

immediately without local trip. ii. Check if C.B. on & carrier receive local trip and Echo signal

send after time delay (according to setting).

8.

If we have two parallel lines, so we have two Telec. Devices ( 4 channel for each device ) We can say : Device one – D1 , Device two – D2 For testing the CBF : D1 and D2 are Healthy Step-1: CBF For Line-1 operates and send two command in the same

time ( DTT-1 through D1 ; ch-2 & DTT-2 through D2 ; ch-2 ) ( CB Trip )

Step-2: CBF For Line-2 operates and send two command in the same time ( DTT-1 through D2 ; ch-3 & DTT-2 through D1 ; ch-3 ) ( CB Trip )



For testing the CBF : one device is Healthy and the other is Faulty Step-5: CBF For Line-1 operates and send ( DTT-1 through D1 ; ch-4

& D2 is failed ) ( Trip )



PAGE NO. 175 OF 191



Step-6 ; CBF For Line-1 operates and send ( D1 is failed & DTT-2 through D2 ; ch-4 ) ( Trip )

Step-7 ; CBF For Line-2 operates and send ( DTT-1 through D2 ; ch-4 & D1 is failed ) ( Trip )

Step-8 ; CBF For Line-2 operates and send ( D2 is failed & DTT-2 through D1 ; ch-4 ) ( Trip )

9.

For each of the previous conditions, check Auto-recloser Initiation:- a. Check auto-recloser initiation from fast tripping relay by

simulation of instantaneous protections. b. Check auto-recloser initiation from intertrip receive relay and

Check in remote end fast instantaneous protections operate which send that intertrip signal.

c. Check auto-recloser blocking initiation from delay or backup protection tripping relay by simulation of delay or backup protection.

d. Check auto-recloser blocking initiation from intertrip receive relay and check in remote end delay or back up protection operate which send that intertrip signal.

10. For each of the previous conditions, check that Carrier Send and Received events are recorded at the Fault or Event recorder for signals initiated from the remote end.

11. Repeat the previous tests at remote end

12. Simulate communication channel failed, and check the operation of the relay on basic scheme.

3.17.2 Directional Earth Fault Protection


1

Following activity should be completed before start the end to end test a. Secondary injection for main relays (Distance, Directional Earth

Fault, and Over-Current). b. Final Settings Applied for the main relays. c. Function Tests for Relay and Control Panels (for proper

command and indications). d. Function Tests in GIS (for proper operation of the breaker) e. Fault & Event Recorders commissioned and properly interfaced. f. Proper Operation of Bus-bar Protection and Circuit Breaker Fail

schemes g. Communication equipment and communication channel is

commissioned and in service

2


3 Check functions and alarms of each communication channels individually by simulation these functions alarms in communication



PAGE NO. 176 OF 191



panel and check functions and alarms in remote end communication panel. Check segregation between functions and alarms and channels. The communication channels with smallest prolonging time value are used for directional earth fault communication scheme and another for inter-tripping send and receive.

4 BLOCKING SCHEME:

Directional blocking scheme Forward Fault:

a. Simulate a forward fault and check there is no initiation of CS to remote end and no CR received. (Be sure the communication channels are healthy).

b. Check tripping instantaneously at setting value.(aided trip) c. Check inter-trip send and receive and which tripping relay

initiate send relay. d. Repeat the previous steps from remote end Check that Trip

Signal should appear. Measure the operating time, use Trip signal from the configured binary output to stop the timer, compare the measured time with the set value of Coordination time in the two ends.

Reverse Fault: a. Simulate a reverse fault and check there is a CS in local end

and CR in the remote end. b. Check there is no tripping in the remote end relay. c. Check the tripping occurred at reverse delay setting time at

local end. d. Starting again and simulate a forward fault in the remote end,

(and reverse in the local end). Check the CS in the local end and CR in the remote end and no tripping appear in the relay of the remote end.

Repeat the previous steps from remote end Check that Trip Signal should not appear.

5 PERMISSIVE SCHEME:

Directional comparison scheme a. Check the communication channels are healthy b. Forward Fault:

On the remote end, simulate a forward fault and check that the carrier send (on the remote end) is generated correctly and verify that the carrier is received locally. This CR will simulate a trip permission Signal reception (Permissive Signal). Simultaneously Simulate an earth Fault in line direction, Check that Trip Signal should appear after set coordination time delay. Use the Trip Signal from the configured binary output to stop the






timer, compare the measured time with the set value of Coordination time. -Reverse Fault: On the remote end, simulate a reverse fault and check that NO carrier is sent and that no carrier is received locally. Simulate an earth Fault in line direction and wait longer than the set value of Coordination time(Tcoord), Check that No Trip Signal should appear. Check that assigned binary output Contact for carrier Send (CS) should operate.

6

WEAK INFEED FUNCTION. Echo only. Open the local Circuit Breaker and simulate a forward fault at the remote and check that a CR (Permissive Signal) is received correctly. Check locally that the DEFR sends (or Echo) a permissive Signal and that it is received correctly at the remote end. Echo and trip. Close Local Circuit Breaker and simulate a forward fault at the remote end. Verify that a CR is received locally (Permissive Signal), and apply residual voltage (DEF with Residual voltage level) with little or no current, Check that the relay will carry out a “Weak in-feed” trip and Send a Permissive Signal (CS) to the remote end and allowing it to carry out a Carrier aided trip also.

7 Check in the fault recorder level of fault voltage, fault current, relay starts, relay trips indication and time.

8 Repeat all the previous tests at the remote end.

9 Simulate a communication failure condition and check the operation of the relays on the basic scheme.



3.18 End To End Test for Under Ground Cable Feeders

3.18.1 Pilot Wire Cable Differential Protection

ITEM REMARKS DONE DESCRIPTION

Ensure that Pilot wire cores are matched between local station and remote station by colors, Continuity, Loop resistance and Insulation resistance.

1.

Adjust the pilot stabilizing resistors and final setting based on the actual measured pilot loop resistance.

2.

Check pilot supervision indications properly if fail or not, it must be correct (pilot open and pilot cross will give pilot open indication in supervision).

3.

Check pilot DC current is within the manufacturer recommended supervision current limits. (If you found current equal zero that means there is crossing in pilot wire).

4.

5. Check supervision voltage send and receive for both substation Using the pilot isolation terminal blocks, simulate pilot failure

conditions: Open circuit, short circuit, cross wired and make sure that the supervision alarms are generated correctly.

6.

Inject current on the over-current starter element or simulate an over-current condition by energizing the start input of the line differential relay.

7.

Check the operating current (pilot relay current and main pilot current) in local and remote substations by current Injection for pilot relay. Check the relay’s output voltage for the injected current. Increase the injected current until the remote breaker trips (While recording the sent and received pilot voltage).

8.

Check inter-trip scheme by Closing local CB then send inter-trip, remote CB will trip. During this, measure send voltage in local substation and measure receive voltage in remote substation and repeat for remote substation.

9.

Check operating time (loop time).

10.

3.18.2 Fiber Optic Cable Differential Protection

REMARKSDONE DESCRIPTION ITEM 1. Ensure that fiber optics pairs are matched between local station

and remote station and that the Optical Line System has been commissioned and is in service.

2. Check fiber optics supervision indications for communication if fail or not, it must be correct.

3. Make sure that the current readings are matching locally and remotely. Increase the current injection and check the operation and





REMARKSDONE DESCRIPTION ITEM tripping of the relay in local and remote substations. ( for all

phases)

Check alarms "inter-trip send and receive faulty" 4. Check supervision voltage send and receive for both substations. 5. Check inter-trip scheme by Closing local CB then send inter-trip,

remote CB will trip. During this, measure send voltage in local substation and measure receive voltage in remote substation and repeat for remote substation.

6.

Check operating time (loop time). 7.



3.19 SCADA POINT LIST CHECK

3.19.1 Commands Tests ITEM DESCRIPTION DONE REMARKS 1. All function and operation tests in the SS must be done 2. Check the wirings of the SCADA Command from RTU. 3. Check the ferrule of Cables.

4. Initiate the Commands from the Control Centre and check the operation at equipments one by one.

5. Confirm that the command from the control center and operation of the equipment same.

6. Take the print of commands & events for record and match.

7.

Make sure that all conditions are tested with positive and negative test conditions. Example of negative test: Selector switch is in local & a close command is received from Electrical control center does NOT close the circuit breaker.

3.19.2 SCADA Back Indication Tests

TEM DESCRIPTION DONE REMARKS 1. All function and operation tests in the SS must be done 2. Check the wirings of the SCADA Back Indications from RTU. 3. Check the ferrules.

4. Initiate the Commands from the Control Centre and check the back indication at RTU and Control Centre.

5. Confirm that the command and Back Indication of the equipment same.

6. Take the print of commands & Back Indication and match.

3.19.3 SCADA Alarms Tests

ITEM DESCRIPTION DONE REMARKS 1. All function and operation tests in the SS must be done. 2. Check the wirings of the SCADA Alarm from RTU. 3. Check the ferrules.

4. Initiate the Alarms from the equipments and check the Alarms at RTU and Control Centre.

5. Confirm that the Alarms initiated and at the RTU and Control Centre are same.

6. Check the alarm label and group alarm label received at the control center are matching the approved point list.

7. Make sure that the alarm types are correct (trip / non-trip or urgent / non-urgent).

8. Make sure that alarm system failure alarm is received at the control center.

9. Take the print from S.O.E. & at RTU and Control Centre and match.




3.20 Metering and Readings through SCADA to ECC


1. Study the schematic diagrams for metering and transducers generating signals for the SCADA.

2. Supply the currents and voltages to the transducers by the secondary injections and take the readings from the Remote Terminal Unit of SCADA.

3. Compare the inputs and the readings at Remote Control Unit.

4. Check the readings of voltages up to two digits, currents up to three digits and frequency up to one digit after decimal point.

5. Check the sums, maximum, minimum, averages values etc. at Remote Terminal Unit of SCADA.

6. Inject current at the transducer inputs and make sure that the current readings are being received correctly at the control center.



PAGE NO. 182 OF 191


3.21 Pre-Energization Confirmation Checks


1.

ALL current circuits of all bays and equipments must be reviewed and checked. All current circuits and terminal blocks screws must be good tightened. The (short and isolate – single earth point – CT ratio) must be according to schematic drawing.

2. All test formats must be checked and signed by contractor and sec engineers.

3. All activities must be done and no Class A snags are remaining. 4. Final trip test activity test format must be checked.

5. All (closing, tripping, alarm, voltage, SCADA, communication, etc.) circuits terminal blocks screws must be good tightened.

6. All VT circuits MCB's closed, fuses in place. All voltage circuits in SS must be reviewed and terminal blocks screws must be good tightened.

7. All supplies to protection, control, switchgear, etc., are normal.

8. No abnormal relay targets, alarms, SCADA SOE indications.

9. All relays have approved settings applied and have been fully tested and are in service.

10. All alarm relay settings are finalized and the relays are locked.

11. Relays that have a backup battery for memory storage have their batteries installed and the temporary battery covers removed.

12. All relays Time and Date settings are correct and reviewed.

13. All snags must be classified and revised. All class A snags must be cleared.

14. All switchgear and other power equipments testing are completed.

15. All protection equipment is properly labeled. 16. All fire/smoke alarm systems are fully tested and in service.

17. All necessary fire fighting equipment is on site and accessible without obstruction.

18. Confirm all men and tools are clear of equipment to be energized and that all personnel are aware of the pending energization.



PAGE NO. 183 OF 191


3.22 During Energization Confirmation Checks


1.

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

2.

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.



d. Directional earth fault relays shall be proven by selectively isolating in service voltages and currents to provide a range of simulated fault conditions. (remove one phase voltage to result summation of another two phases and make short circuit for another two current phases to obtain the third phase as a input current to the relay) according to obtained values of voltage, current and angle the relay action. Make reverse polarity and check the relay action.

e. For REF and bus differential relays, check to ensure minimal spill currents in service. Test the differential circuit by shorting 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 at 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)



PAGE NO. 184 OF 191



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.



3.

After two transformers have been successfully energized, perform a back to back test to check differential protection measurements are ok. Parallel the two energized transformers. Switch the tap changers to manual operation and manually raise or lower one of the two transformers from nominal tap to create a voltage difference and circulating current. Check the current readings in the CT secondary circuits. Check that all protection relays are working properly.

4. After the substation is properly loaded, check parallel operation and master / follower scheme for automatic voltage regulation relays.



PAGE NO. 185 OF 191


3.23 On Load tests

3.23.1 On Load tests for CT/VT Circuits & Transformer Inspection.


1. Visually inspect CT compartments in the GIS, Switchgear …etc and make sure there is no abnormal sound.

2. Visually inspect the Power Transformer & Auxiliary Transformers and make sure there is no abnormal sound.

3.

Make your own measurements of the secondary current for all phases and in neutral with Clamp meter in metering and protection cores, the values should be in accordance with the ratios of the cores.

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

5. For protection devices with built in metering functions check current, voltage magnitudes, and phase angles, real and reactive power.

6. Check the direction of power, active component and reactive components (power in line direction is positive) and check power factor

7. For VT Circuit check Secondary Voltage between phases and the neutral with volt meter which should be in accordance to the VT ratio.

8. Check phase rotation with a phase rotation meter connected across the three phases.

3.23.2 On Load Line/Cable Differential Protection Stability & Sensitivity

REMARKSDONE DESCRIPTION ITEM

Ensure that the new Feeder was energized without any load for one

hour at least before on load Test. 1.

Ensure to decrease the tripping time of over current protection to less

than 0.5 sec (if DMT O\C). 2.

3. Ensure that the tripping of Line or Cable differential Relay is ISOLATED to prevent false operation of relay.


5. If necessary, isolate any relay operated alarm contacts and any breaker failure initiation contacts as per the scheme

6. Ensure that the Feeder is loaded by 25% at least from its rated current.

7. Read phases currents, they must be balanced and measure the differential current must be close to zero in stable case.



PAGE NO. 186 OF 191


REMARKSDONEDESCRIPTION ITEM8. Check the relay performance (Trip Action) at unstable condition by

reversing the current direction by one of the following methods : Reverse the current direction from relay software. Reverse two Current phases by reversing current wire (must prevent opening of CT circuit by making short circuit for current pass). By shorting one current phase with neutral to make current unbalance

9. If the differential current is lower than the relay setting, reduce the setting of the relay to observe its operation.

10. Normalize the relay setting 11. Normalize the CT circuit (Shorted or cross wired) or the software

internal current direction. 12. Reset the relay to make sure that any operated trip / alarm / CBF start

contacts (latching or non-latching) have normalized 13. Normalize the isolated trip links and any isolated contacts (alarm,

breaker fail …etc) 14. Ensure that the tripping time of over current protection as final

setting after finished the test (if DMT O\C).

3.23.3 On Load Confirmation of Relay Directionality

(Distance / Directional Over-Current and directional Earth Fault protections)

REMARKSDONEDESCRIPTION ITEM Use test plug to isolate tripping circuit and take all precautions to prevent any current circuit opening by using good type of jumper wires for shorting CT plug current terminals.

1.

For relays that rely on fiber communication to send inter-trip signals, Isolate tripping facility on both sides of the line (local and remote end) to prevent accidental disconnection of the power circuit.

2.

Isolate any relay operated alarm contacts and any breaker failure initiation contacts as per the scheme

3.

Ensure that VT fail function of directional Relay is switched off to prevent relay block.

4.

5. Ensure that the Feeder is loaded by 25% rated current at least. Ensure to decrease the tripping time of over current protection to less than 0.5 sec (if DMT O/C).

6.

Measure the currents magnitude with phase angles and confirm that angle measured is approximately same as on power meter of this circuit and measurements with system control.

7.

Compare the measured values of phase angles at local end with the ones measured at remote end. Results at both ends should be approximately 180 degrees out of phase.

8.

For numerical relays, direction can be verified from relay on load measurements by relay as explained in respective relay manuals.

9.



PAGE NO. 187 OF 191


REMARKS DONEDESCRIPTION ITEM Check the Power direction by checking the current direction, if the feeder export in this case the active power will be forward (+ve), and Vice versa the power will be reverse (–ve)

10.

For export feeder (active power is +ve, and reactive power is +ve for Lagging and – ve for Leading Power factor.)

a. Remove one red phase voltage, ensure that the distance protection will pickup and trip for a forward fault (Z1, Z2 etc)

b. Ensure that the directional O/C protection picks up and trip for that forward direction. Swap polarity of the phase current R and protection will not operate.

c. If the distance protection picks up or trips for a reverse fault (Z3’, Z4, Z5, Zreverse) …etc then the directionality is incorrect.

d. If the directional over current protection not operate check setting values and decrease until operate or check directionality.

For import feeder (active power is –ve, and reactive power is -ve) for Lagging and +ve reactive power for Leading Power factor.)

a. Remove one phase red voltage, ensure that the distance protection will pickup and trip for a reverse fault (Z3’, Z4, Z5, Zreverse …etc)

b. Ensure that the directional O/C protection will not operate for that reverse direction. Swap the polarity of current phase R and ensure that protection will operate at setting decreased to load current.

c. If the distance protection picks up or trips for a forward fault (Z1, Z2) …etc then the directionality is incorrect.

For directional earth fault: (remove one phase voltage to result summation of another two phases and make short circuit for another two current phases to obtain the third phase as an input current to the relay) according to obtained values of voltage, current and angle the relay action. Make reverse polarity and check the relay action.

11.

Repeat the previous procedure for Yellow and Blue voltage phases, and check relay performance.

12.

Reset the relay to make sure that any operated trip / alarm / CBF start contacts (latching or non-latching) have normalized

13.

Normalize the isolated trip links and any isolated contacts (alarm, breaker fail …etc)

14.

Ensure that all hardware connections are normalized ok as per drawing and tightness.

15.

Ensure that the tripping of Directional relay is in services after finished the test.

16.

Ensure that the tripping time of over current protection as final setting after finished the test (if DMT O/C).

17.



PAGE NO. 188 OF 191


3.23.4 Transformer Differential Protection on Load Stability Tests


1. This test should only be performed after the transformer has been energized for at least 24 hours with no load, and all temperature readings and indications are healthy.

2.

To load a transformer, start with approximately 10% rated current. And check operating current in differential relay, so the loading should be gradually and checking operating and restraint currents of the relay.

3. Check the phase angle between primary and secondary current for each phase depending on the transformer vector group.

4. Check the readings of Primary, Secondary and differential Currents (spill currents between phases)

5. If deviation in expected values of operating and restraint current for all phases then isolate the differential relay tripping circuit and solve the problem in current circuit or in relay setting.

3.23.5 Restricted Earth Fault Protection on Load Stability Tests

REMARKS DONE DESCRIPTION ITEM

This test should only be performed after the transformer has been energized for at least 24 hours with no load, and all temperature readings and indications are healthy.

1.

2. Ensure that the transformer is loaded by 25% at least from its rated current.

3. By mean of clamp meter, check the current balance of all phases or read the current and angles of phases if the relay is digital.

4. For high impedance REF, by using mean of volt meter, ensure that the voltage across relay coil terminal almost equal to zero which related to differential current.

3.23.6 Bus Bar Protection on Load Stability Tests

ITEM DESCRIPTION DONE REMARKS 1. With the bus-bar loaded with at least 25% of the rated current:

2.

Measure the current and angle of all current circuits in all bays and in BBP panels for discrimination and check zones. Check stable current Is and differential current Id values in the discrimination zones and check zone. Differential current Id should be zero





3.23.7 Stuck Breaker Protection On-Load Stability & Sensitivity Tests


1

Stability on-load: With at least 25% load on the circuit: Verify with a clip on meter or a phase angle meter that the CT secondary currents are correct depending on CT ratio for incomer and bus section breaker CT’s. Verify with clip on meter that the summation current of both CT secondary circuits is matching to the summation of load of the bus section. Verify the reading on the relay in secondary and primary current to equal the summation of load for that bus section. Repeat the stability readings for all phases (R, Y, and B).



S/S Name / No.: …………………… Bay No.: ……………..


4.0 CHECK LIST OF SUBSTATION AUTOMATION SYSTEM (SAS)

4.1 The contractor shall submit the test procedure for SAS equipments, devices and relays 6 months prior to start pre-commissioning for approval. These tests shall be based on IEC 61850 Substation Automation System (SAS).


1 EQUIPMENT



S/S Name / No.: …………………… Bay No.: ……………..


5.0 CHECK LIST OF SUBSTATION NOISE LEVELS MEASUREMENT

4.1 The Contractor shall submit the procedure, arrangement and schedule for noise levels measurement at the substation for approval according to the following scenario.


1.

Measurement of average background noise levels at substation site after the mechanical completion of the project during day time and night time prior to energization of Substation Transformers.

2.

Measurement of average Transformers noise level at ONAN rating at the site for comparison with the value measured in the factory and declared by the transformer manufacturer. (Note: the expected measured average noise level value is equal to measured transformer noise level carried out at transformer factory per IEC 60076-10 + the actual average background noise level measured at substation site as stated in point no.1).

3.

Measurement of Noise levels at substation boundaries. The result of noise levels measured at boundaries shall not exceed the value specified in TES-P-119.02, Rev.0, clause 5.2.6 of 65dB(A) during day time between (06:00 – 22:00hrs.) and 55dB(A) during nigh time between (22:00 -06:00hrs.)