RUWAIS LNG PROJECT
ELECTRICAL DESIGN BASIS
COMPANY DOCUMENT REF. CONTRACTOR DOC. REF.
RLNG-000-EL-BOD-0001 215122C-000-JSD-1600-0001
REVISION: 1
PAGE 1 OF 43
ADNOC GAS
ELECTRICAL DESIGN BASIS
COMPANY Contract No.
4700022871
JV TJN RUWAIS Contract No
215122C
Document Class
Class 1
Document Category (for Class 1)
Category 2
OPERATING CENTER Contract No.
OPERATING CENTER Doc Ref.
SS-000-13802-0001
1
IFC - Issued for Construction
13-Dec-2024
J. Ghosh
0B
Issued for Client Review
15-Nov-2024
J. Ghosh
0A
Issued for Client Review
29-Aug-2024
J. Ghosh
0
IFA -Issue for Approval
13-May-2024
J. Ghosh
M. Sano E. Papeil S. Pandey A. Ghosh
M. Sano E. Papeil S. Pandey A. Ghosh
M. Sano E. Papeil S. Pandey A. Ghosh
M. Sano E. Papeil R. Dewangan A. Ghosh
S. Deilles
K. Fuji
S. Deilles
K. Fuji
S. Deilles
K. Fuji
S. Deilles
K. Fuji
Rev
Revision Purpose
Date
Prepared by
Checked by
Approved by
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REVISION: 1
PAGE 2 OF 43
Table of Contents
Contents
Page
1.0
INTRODUCTION … 4
1.1 Scope of the Document … 4
1.2 Holds List … 5
1.3 References … 5
1.4 Definitions and Abbreviations … 6
1.5 Codes and Standards … 8
2.0 Design … 10
2.1 Hazardous Area Classification … 10
2.2 Electrical Distribution … 11
2.3 Electrical Equipment … 16
2.4 Electrical Protection and Control System … 20
2.5 Substation … 26
2.6 Earthing and Lightning Protection System … 28
2.7
Lighting And Sockets Outlets … 32
2.8 Cabling and Cable Support System … 38
2.9 Cathodic Protection System … 40
2.10 Electrical Heat Tracing System … 41
2.11 UPS System … 41
2.12 ECMS System … 42
2.13 Software Tools … 43
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REVISION: 1
PAGE 3 OF 43
Table of Changes compared to previous revision
Paragraph
Modification description
Remarks / Origin
This document has been updated from the FEED “359665-0000-070-BD-1680- 001_Rev 0” document. Note 4 of Table #1 updated.
2.2.7
2.7.4.6 & 2.7.4.8
Updated
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1.0
INTRODUCTION
The ADNOC Ruwais LNG Project is a two train, near net-zero electrically driven LNG facility, targeting international markets. The feed gas for the project is supplied from the Habshan Gas Processing Plant via a new export gas pipeline. The plant will have two 4.8 MTPA (nominal capacity) electric driven LNG Trains with associated LNG storage/marine export facilities and utilities.
Figure 1 – Project Context
The ADNOC Ruwais LNG Project foresees the following main components at the facility:
• Onshore LNG Liquefaction facilities for 2 x 4.8 MTPA electrically driven LNG Trains (9.6MTPA total)
• Common facilities including inlet receiving facilities, LNG storage, BOG handling, flare, refrigerant
storage and support buildings.
• Utilities to support the facilities including import power from the national grid.
• Marine facilities for LNG export and bunkering.
1.1
Scope of the Document
This design basis defines the requirements for Electrical Work design for ADNOC Ruwais LNG project.
This design basis covers the minimum design codes, safety aspects, standard requirements and procedures to be followed for the engineering, design and installation of following:
• Hazardous Area Classification • Electrical Distribution • Electrical Equipment • Electrical Protection and Control System • Substations • Earthing and Lightning Protection • Lighting System • Cabling and Cable Support System • Cathodic Protection • Electric Heat Tracing • UPS • ECMS
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REVISION: 1
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1.2
Holds List
HOLD
DESCRIPTION
1
2
3
4
5
6
7
Deleted
Deleted
Deleted
Deleted
Interface requirement with Transco
Deleted
Deleted
1.3
References
Company Doc. No.
RLNG-000-EL-SP-0011
RLNG-000-EL-SP-0002
RLNG-000-EL-SP-0008
RLNG-000-EL-SP-0009
RLNG-000-EL-SP-0022
RLNG-000-EL-SP-0016
RLNG-000-EL-SP-0010
RLNG-000-EL-SP-0003
RLNG-000-EL-SP-0020
Project Document Number 215122C-000-JSS- 1697-5001 215122C-000-JSS- 1640-0001
215122C-000-JSS- 1650-0002
215122C-000-JSS- 1654-0001
215122C-000-JSS- 1650-5005
215122C-000-JSS- 1682-5001
215122C-000-JSD- 1600-0003
215122C-000-JSS- 1690-0001
215122C-000-JSS- 1657-5001
Document Title
Specification for Emergency Generator Package
Specification for Power Transformer
Specification for Air Insulated High Voltage Switchgear and Controlgear
Specification for Low Voltage Switchgear and Controlgear
Specification for Bus Ducts
Specification for Electrical Heat Tracing
Specification for Electrical Items on Packaged Equipment
Specification for Induction Motors
Specification for Lighting and Small Power Distribution Boards
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Company Doc. No.
RLNG-000-EL-SP-0007
RLNG-000-EL-SP-0005
RLNG-000-EL-SP-0014
RLNG-000-EL-SP-0004
RLNG-000-EL-SP-0006
RLNG-000-EL-SP-0012
RLNG-000-EL-SP-0013
RLNG-000-EL-SP-0015
RLNG-000-EL-SP-5102
RLNG-000-EL-SP-5103
RLNG-000-HS-PP-0001
Project Document Number
215122C-000-JSS- 1670-0001
215122C-000-JSS- 1693-0001
215122C-000-JSS- 1661-5001
215122C-000-JSS- 1690-0002
215122C-000-JSS- 1620-0001
215122C-000-JSS- 1640-5002
215122C-000-JSS- 1656-5001
215122C-000-JSS- 1651-5001
215122C-000-JSD- 1600-5102
215122C-000-JSD- 1600-5101
215122C-000-JSD- 1900-0001
Document Title
Specification for Static Uninterruptible Power Supply
Specification for Electrical Adjustable Speed Drive System
Specification for Electrical Control and Monitoring System
Specification for Synchronous Motors
Specification for Electrical Power, Control and Earthing Cables
Specification for Neutral Earthing Resistors
Specification for Power Factor Improvement and Harmonic Filter Equipment.
Specification for Gas Insulated Switchgear and Controlgear >52kV
Lighting and Small Power philosophy
Electrical Cable selection and Sizing philosophy
Design HSE Philosophy
RLNG-000-PR-PP-0001
215122C-000-CN-0008- 0006
Drainage Philosophy
RLNG-000-PM-BOD- 2002
RLNG-RFI-EL-0001
RLNG-000-PM-BOD- 2002
215122C-000-PP-2002
Project Basis of Design
215122C-000-RFI-EL- 0001
215122C-000-PP-2002
TRANSCO Information
Project Basis of Design
1.4
Definitions and Abbreviations
COMPANY
CONTRACTOR
Deleted
ABU DHABI NATIONAL OIL COMPANY (ADNOC) P.J.S.C. TJN Ruwais, Joint Venture of Technip Energies France-Abu Dhabi, JGC Corporation and National Marines Dredging Company (NMDC)
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EPC ADOC POC YOC COMPANY PURCHASER
Abbreviation AC ANSI ASD DC DOL ECAS ECMS EDG EMC ESD ETAP
Abbreviation F&G GIS HV HVAC ICSS IEC IP ISO kV LNG LV MCC MCCB MVA OLTC PLC PCC RCCB UPS
Engineering Procurement Construction Abu Dhabi Operating Center - National Marines Dredging Company Paris Operating Center - Technip Energies Yokohama Operating Center - JGC Corporation ABU DHABI NATIONAL OIL COMPANY (ADNOC) P.J.S.C. CONTRACTOR in charge of the requisitioning activities
Definition Alternating Current American National Standards Institute Adjustable Speed Drive Direct Current Direct On Line Emirates Conformity Assessment Scheme Electrical Control and Monitoring System Emergency Diesel Generator Electromagnetic Compatibility Emergency Shutdown System Electrical Transient Analysis Program
Definition Fire and Gas Gas Insulated Switchgear High Voltage Heating, Ventilation and Air Conditioning Integrated Control and Safety System International Electrotechnical Commission Ingress Protection International Organization for Standardization Kilo Volt Liquefied Natural Gas Low Voltage Motor Control Center Moulded Case Circuit Breaker Mega Volt Ampere On Load Tap Changer Programable Logic Controller Power Control Center Residual Current Circuit Breaker Uninterruptible Power Supply
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1.5
Codes and Standards
The equipment, materials, design and installation of the electrical facilities shall conform to the local laws, the following regulations, international standards, and the applicable portions of the latest edition of the industry codes and standards. Design will generally be based on IEC standards, and more precisely will be in accordance with following standard or standard series:
Codes & Standards
Document Title
IEC 60034
IEC 60038
IEC 60071
IEC 60076
IEC 60079
IEC 60099
IEC 60332
IEC 60364
IEC 60529
IEC 60617-DB
IEC 60754-1
IEC 60754-2
Rotating electrical machines - Applicable parts.
IEC standard voltages.
Insulation coordination.
Power transformers - Applicable part.
Explosive atmospheres - Applicable parts.
Surge arresters - Applicable parts.
Tests on electric and optical fibre cables under fire conditions - Applicable parts.
Low-voltage electrical installations - Applicable parts.
Degrees of protection provided by enclosures (IP Code).
Graphical symbols for diagrams.
Test on gases evolved during combustion of materials from cables - Part 1: Determination of the halogen acid gas content.
Test on gases evolved during combustion of materials from cables - Part 2: Determination of acidity (by pH measurement) and conductivity.
IEC 60794-4-10
Optical fibre cables - Part 4-10: Family specification - Optical ground wires (OPGW) along electrical power lines.
IEC 60831
IEC 60871
IEC 60909
IEC 60947
IEC 61000
IEC 61034-2
Shunt power capacitors of the self-healing type for A.C. systems having a rated voltage up to and including 1000 V.
Shunt capacitors for a.c. power systems having a rated voltage above 1000 V (All Parts)
Short circuit current calculation in three phase A.C. systems- Applicable parts.
Low voltage switchgear and controlgear - Applicable parts.
Electromagnetic Compatibility (EMC) - Applicable parts.
Measurement of smoke density of cables burning under defined conditions.
IEC 61039
Classification of insulating liquids.
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Codes & Standards
Document Title
IEC 61089
IEC 61109
IEC 61363
IEC 61439
IEC 61466-1
IEC 61466-2
IEC TR 61641
IEC 61869
IEC 61936
IEC 62052-11
IEC 62053-21
IEC 62271
IEC 62271-200
IEC 62271-203
IEC 62305
IEC 62351
IEC 62485-2
IECEx 02
Round wire concentric lay overhead electrical stranded conductors.
Insulators for overhead lines - Composite suspension and tension insulators for a.c. systems with a nominal voltage greater than 1000 V
- Definitions, test methods and acceptance criteria.
Electrical installations of ships and mobile and fixed offshore units - Part 1: Procedures for calculating short-circuit currents in three-phase a.c.
Low voltage switchgear and controlgear assemblies - Applicable parts.
Composite string insulator units for overhead lines with a nominal voltage greater than 1000 V - Part 1: Standard strength classes and end fittings.
Composite string insulator units for overhead lines with a nominal voltage greater than 1000 V - Part 2: Dimensional and electrical characteristics.
Enclosed LV Switchgear and Controlgear – Guide for testing under conditions of arcing due to internal fault.
Instrument Transformers - Applicable parts.
Power installations exceeding 1 kV a.c. and 1.5kV DC- Applicable parts.
Electricity metering equipment - General requirements, tests and test conditions - Part 11: Metering equipment.
Electricity metering equipment - Particular requirements - Part 21: Static meters for AC active energy (classes 0,5, 1 and 2).
High Voltage Switchgear and Control gear- Applicable parts.
AC metal-enclosed switchgear and controlgear for rated voltages above 1 kV and up to including 52 kV
AC gas-insulated metal-enclosed switchgear for rated voltages above 52 kV
Protection against lightning - Applicable parts.
Power systems management and associated information exchange – Data and communications security- Applicable.
Safety requirements for secondary batteries and battery installations - Part 2: Stationary batteries.
IEC System for Certification to Standards relating to Equipment for use in Explosive Atmospheres (IECEx System) IECEx Certified Equipment Scheme covering equipment for use in explosive atmospheres – Rules of Procedure.
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Codes & Standards
Document Title
IEC TR 60083
IEC TR 62271-303
BS EN 1838
IEEE 1584
IEEE 80
IEEE C37.99
IEEE 519
Plugs and socket outlets for domestic and similar general use standardized in member countries of IEC.
High voltage switchgear and control gear. Use and handling of Sulphur hexafluoride (SF6) in high voltage switchgear and control gear.
Lighting Applications. Emergency Lighting
IEEE Guide for Performing Arc-Flash Hazard Calculations.
IEEE Guide for Safety in AC Substation Grounding.
IEEE Guide for Protection of Shunt Capacitor Banks.
IEEE Recommended Practice and Requirements for Harmonic Control in Electric Power System
EI-15
Part 15: Area Classification for installations handling flammable fluids.
TRANSCO Standards shall be applied to all relevant and applicable equipment and interfaces. Design details are required to be accepted/ approved by TRANSCO before implementation. TRANSCO standards shall apply to all GRID equipment associated with overhead lines and 132kV incomer cables from OHL Gantry to the 132kV GIS in RLNG Main Intake substation. TRANSCO standards shall be applied for the tariff metering CT/VTs in the 132kV GIS.
Language and System of units: All Documents, drawings, data, nameplate, warning plate shall be in English Language. Metric (SI) system shall be applied.
2.0
DESIGN
2.1
Hazardous Area Classification
2.1.1 Classification of Hazardous Areas
Safety group shall prepare the area classification which shall be used to allow the correct protection concept and ratings to be assigned to equipment. The area classification shall show the extent and type of zone selected for each process area, based on the grade of release, and the degree and availability of ventilation for the area. Classification of areas shall be prepared in accordance with EI-15 and other references as per Design HSE Philosophy (RLNG-000-HS-PP-0001).
2.1.2 Selection of apparatus
Electrical apparatus shall be selected for use in hazardous areas in accordance with IEC 60079-14 and the following main criteria:
• Type of protection of apparatus in relation to Zone risk.
• Temperature classification of apparatus in relation to ignition temperature of gases, vapors and dusts
involved.
• Apparatus sub-group in relation to the relevant properties of the gases and vapors involved.
• Apparatus construction and enclosure in relation to the environmental conditions.
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2.1.3 Certification
Equipment and materials for use in any hazardous area shall be tested and certified by an IECEx approved certification body and ECAS. The supplier shall always provide a Certificate of Conformity for any equipment or materials showing the appropriate certification and standards which apply.
2.1.4 Electrical equipment within process areas (i.e. Inlet Facilities, Liquefaction, LNG Storage, Boil Off Gas, Export / Loading, Refrigerant Storage and Flare) shall comply with Zone 2 requirements as a minimum with the exception of all outdoor transformers, outdoor resistor banks for Harmonic Filters which may be non- hazardous area rated when located in a non-hazardous area within the process area. Hazardous area certification requirement for individual electrical equipment items will be defined on the associated data sheet for each item.
Electrical equipment (e.g. motors, heaters, etc.) outside of the process areas may be non-certified industrial equipment unless the location of the equipment falls within a hazardous area.
Electrical equipment located within pressurised equipment buildings located in the process and utility areas will be non-certified as the internal space within the building is classified as a safe area with gas detection at the HVAC air intakes.
All Electrical bulks, as defined in the following list, in outdoor locations used across process and utility areas shall be certified Zone 2 regardless of the hazardous area classification of their location:
• • • • • •
Lighting fixtures and accessories Junction boxes Motor control stations Welding sockets / convenience outlets Cable glands and blanking plugs Local field distribution boards
All Electrical bulks, as defined above, installed outside of the process and utility areas (i.e. industrial and non-industrial buildings area and gate houses) may be non-certified industrial equipment.
All external equipment on process facilities required to operate in emergency conditions (essential and vital) shall be suitable for Zone 1.
In the event of an emergency (confirmed fire and gas) all the Zone 2 and unclassified equipment shall be de- energised (electrical power isolation) to avoid ignition potential.
2.2
Electrical Distribution
Reliability shall be achieved by the selection of equipment and components that have been designed, manufactured and tested to the applicable National and International standards, and that have a record of reliable operation in similar environments and services.
2.2.1 Design Margin
Equipment shall not generally be utilised to the full extent of its rating. A minimum of 10% spare margin, over the calculated peak load demand at the end of EPC stage shall be considered (for future use) for major electrical distribution equipment such as power transformers and main switchgear. For transformers fans may be considered to provide further spare margin if suitable for the application. The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party. .
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2.2.2 Design Life
Electrical equipment shall have a minimum design life of 30 years.
2.2.3 System Availability
Distribution systems shall usually be secondary selective from the power intake substation to the main LV distribution switchgear. Single radial systems may be used if the plant (or building) is of a type or in a place where these are standard practice. For secondary selective systems, the rating of distribution equipment shall allow any one transformer or switchboard feeder to be taken out of service without preventing the plant from operating normally.
2.2.4 Main Power Supply
The 400kV/132kV Grid Substation will be executed by TRANSCO outside of the plot limits of Ruwais LNG Plant. The TRANSCO grid substation will be built, owned and operated by TRANSCO. Three 132kV OHL circuits emanate from 400/132kV TRANSCO Substation and land at OHL to Cable conversion yard near the plant battery limit and further connect to 132kV GIS inside the Plant Main Substation through cables. The point of common coupling (PCC) shall be at Plant 132kV GIS Incomers.
References shall be made to TRANSCO Specifications for Overhead Lines and TRANSCO Substation.
Supply characteristics of the external source at PCC are as mentioned below and shall be used in the calculation and sizing of equipment for the Project (refer TRANSCO Information, RLNG-RFI-EL-0001).
Voltage and variation (steady state)
132kV, +5%, -5%
Frequency and variation (steady state)
50Hz, +1%, -1%
Max Min X/R Ratio
Three phase short circuit level at PCC 35kA
13kA
38
Single phase short circuit level at PCC
(TBD)
8kA 84
Power factor at PCC shall be designed to be maintained at 0.95 and above.
Individual harmonics (Current & Voltage) injected into the network by the plant load shall not exceed the distortion limits as per TRANSCO standard at the point of common coupling (PCC). The total Harmonic distortion (THD) at PCC shall be within the requirements specified in IEEE 519, Table 1.
2.2.5 Emergency Power Supply
Emergency diesel generators (EDG) shall be provided to supply emergency power to defined consumers in the event of a power outage. EDG’s will be distributed throughout the plant where required and shall tie in at the plant electrical LV distribution level. Typical consumers able to be supplied by EDG will be emergency lighting, UPS, HVAC, fire water jockey pump, and critical electric heat tracing, Aviation Lighting Loads and general plant alarm systems.
For testing purposes, facilities shall be provided to allow short time parallel operation of the emergency diesel generator(s) with the main power supply to carry out periodic load test.
A Diesel day tank capacity for 12 Hours shall be provided.
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EDG shall have a battery primary and an air or hydraulic secondary start system. Each system shall have sufficient stored energy to provide a minimum of six starts equivalent to 180 seconds of cranking time at an ambient temperature of 5 °C.
2.2.6 Uninterruptible Power Supply (AC UPS and DC UPS)
UPS shall be dual redundant and adequately sized to handle the specific duty involved. Batteries shall be rated to supply the load for the following autonomy periods:
a) 480 min for critical equipment related to life saving (F&G, critical Telecoms, CCTV and PA System)
b) 30 min for non-critical equipment (Non-critical telecoms, HVAC Control panel)
c)
45 min for non-critical equipment (ICSS, EDP (#))
d) 90 min for ECMS system
e) 480 min for Electrical switchgears (DC UPS).
(#) Note for Emergency Depressurisation (EDP) functions, the 45 minutes autonomy time is a minimum requirement, to be confirmed following outcome of Process depressurisation study during later phase of the project execution stage.
2.2.7 Utilisation Voltages & System Frequency
Nominal system voltage shall be selected from IEC 60038 as given in the below Table. Highest voltages corresponding to nominal voltages shall be as given in IEC 60038. System Frequency is 50Hz.
Table #1: System Voltage & Frequency
Service
Voltage
Grid supply at 132 kV
132 kV AC
Primary HV Distribution
11 kV AC
Secondary HV Distribution
6.6 kV AC
Secondary LV Distribution
690 V, 415 V AC
Phase/ Wire Three Phase, Three Wire Three Phase, Three Wire Three Phase, Three Wire Three Phase, Three Wire/ Four Wire
System Earthing
Resistance earthed
Resistance earthed
Resistance earthed
415 V solidly earthed; 690 V resistance earthed
Motors <0.18 kW
240 V AC
Motors >0.18 kW<160 kW
Motors >160 kW<315 kW
Motors >315 kW<3000 kW
690 V AC, 415VAC (NOTE 1) 690 V, 415V, 6.6kV or 11kV AC (NOTE 5)
6.6 kV or 11 kV AC
Motors >3000 kW
11 kV AC
Single Phase, Two Wire
- Earth Three Phase, Three Wire
Three Phase, Three Wire
Three Phase, Three Wire Three Phase, Three Wire
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Service Three phase distribution boards, cathodic protection transformer rectifier unit Single phase distribution boards, cathodic protection transformer rectifier units
Voltage
415 V, 690 V AC
Phase/ Wire Three Phase, Three/Four Wire
System Earthing
415 V solidly earthed 690 V resistance earthed
240 V AC
Single Phase, Two Wire
- Earth
Solidly earthed
Power sockets
240 V AC
Welding receptacles
415 V AC
Lighting final circuit, anti- condensation heaters
240 V AC
Instrument power supply
240 V AC
Single Phase, Two Wire
- Earth Three Phase, Four Wire
- Earth Single Phase, Two Wire
- Earth Single Phase, Two Wire
- Earth
Solidly earthed
Solidly earthed
Solidly earthed
Solidly earthed
Control voltage for switchgears including spring charging motors Control voltage for contactors
ECMS cabinets, monitors, printers and other peripheral devices
Process thyristor control heaters
110 V DC
Two Wire
Unearthed
240 V AC
Single Phase, Two Wire
- Earth
Solidly earthed
240 V AC
Single Phase, Two Wire
- Earth
415 V, 690 V AC
Three Phase, Three/Four Wire
Single Phase, Two Wire
- Earth OR Three Phase, Four Wire
- Earth Two Wire
Solidly earthed
415 V solidly earthed 690 V resistance earthed
Solidly earthed
Unearthed
AC Uninterruptible Power Supply
415V or 240 V AC
DC Battery Charger
110 V DC
NOTE 1: 415V or 690V AC shall be applicable for HVAC system motors. Building (e.g CCB, Jetty Control Bldg.) and Non-process building Motors shall be on 415VAC. NOTE 2: The steady state System Voltage and Frequency variation shall be +/- 5% and +/-1% respectively. NOTE 3: The Transient state Voltage variations shall be +/- 10% with recovery time of 1.5sec. The Transient state Frequency variations shall be +/- 6% with recovery time of 5sec. NOTE 4: The DC Voltage variations shall be +/- 10%. The maximum DC Voltage variation is with normal operation and with AC supply. NOTE 5: 415V shall be applicable for LV VSD or Softstarter driven motors and is subject to COMPANY approval.
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2.2.8 System Design
2.2.8.1 Site Conditions
a) Outdoor
Outdoor atmosphere shall be regarded as dusty, sulfurous and corrosive as common encountered in petroleum installations. Occurrence of internal condensation shall be considered in the design.
Conditions, such as air and soil temperatures, soil thermal resistivity and sun radiation shall be taken into account in the electrical design in general and in cable sizing calculations. Electrical equipment shall be chosen with proper temperature rating. Direct sun radiation shall be taken into account for electrical equipment installed outdoor. For detailed environmental and site data refer Project Doc No : RLNG-000-PM-BOD-2002.
• Altitude:
Less than 1000 m above mean sea level
• Maximum ambient temperature: 54 oC (NOTE 2)
• Outdoor hottest monthly average:
• Annual average:
• Minimum :
• Relative humidity:
• Soil temperature:
• Soil thermal resistivity:
48 oC
34 oC
5 oC
97% at 43 oC
38 oC
2.5 K.m/W
• Maximum Solar Radiation: 946 W/m2
• Basic Wind speed criteria : Refer “RLNG-000-PM-BOD-2002”
• Black Body Temperature +87 oC
NOTE 2: Design temperature of 54 Deg C shall be considered for outdoor bulk materials such as Lighting Fixtures, DBs, JBs, Sockets, etc. Design temperature for the equipment shall follow the respective data sheet.
b) Indoor
In general, indoor locations for electrical equipment shall be HVAC (dual) controlled for the following conditions:
•
Indoor maximum temperature:
• Relative humidity:
40 oC
100%
2.2.8.2 System Calculations
The following calculations shall be performed for each facility:
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• Earthing Calculations as per IEEE recommendations.
• Cable Sizing Calculations
• Load Flow studies
• Short Circuit studies
• Voltage Drop Calculations
• Motor Starting studies for the largest motor (Dynamic Motor starting for Large Compressors).
• Transformer Sizing Study
• Harmonic Analysis, including SSTI, SSCI and SSSO studies, resonance analysis
•
Impact of sudden trip of the large capacity drives on the grid network
• Assessment studies for dynamic voltage recovery system
• Lightning Risk assessment studies (IEC 62305) and Lightning protection study
• Arc Flash studies
• EMC/EMI studies
2.3
Electrical Equipment
2.3.1 Transformer
2.3.1.1
2.3.1.2
2.3.1.3
2.3.1.4
2.3.1.5
2.3.1.6
Power and distribution transformers shall comply with IEC 60076 and RLNG-000-EL-SP- 0002.
Unless otherwise specified, liquid-immersed transformers up to 2000 kVA shall be hermetically sealed type. Transformers rated above 2000 kVA and up to 3150 kVA may be either hermetically sealed or of the conservator type. Unless otherwise specified in the data sheet liquid-immersed transformers above 3150 kVA shall be conservator type.
Unless otherwise specified, liquid immersed transformers rated greater than 10 MVA shall be provided with two stages of forced cooling, for example KNAN / KNAF.
Transformers with secondary voltage up to 11 kV shall have Dyn11 vector group unless otherwise approved by COMPANY. Dzn0 vector group shall be used when it is necessary to introduce phase shift to align vectors with Dyn11 transformers.
Transformer insulating fluid shall be of Synthetic or Natural Ester Oil type 9 with fire point greater than 300 deg C.
For transformer with full load current rating of 1250 A and above, the low voltage connections may be either:
i. Cast resin insulated solid bus ducts.
ii. Single core cables.
2.3.1.7
OLTC shall be provided for transformers where it becomes necessary to satisfy the voltage regulation requirements.
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2.3.1.8
OLTC time delays shall be set to exceed the run-up time of the largest motor downstream of the transformer to avoid tap changer hunting during starting which in turn could cause unnecessary voltage swings.
2.3.2 High Voltage Switchgear above 52kV
2.3.2.1
2.3.2.3
2.3.2.3
2.3.2.4
2.3.2.5
2.3.2.6
2.3.2.7
2.3.2.8
2.3.2.9
Switchgear shall comply with IEC 62271-203 and Project Specification RLNG-000-EL-SP- 0015.
132kV Substation interfacing with TRANSCO incoming supply shall be of a 4 Bus GIS switchboard configuration.
The GIS shall be of the modular design and capable of extension in the future by the addition of extra feeders, bus couplers, bus bars, circuit breakers, disconnect, and other switchgear components without necessarily dismantling any major parts of the equipment.
In case of any internal fault in a bus bar, disconnect switch, or circuit breaker, repair work must be possible without shutting down the complete switchgear, and at least one bus bar and the undisturbed feeders must remain in operation.
Automatic pressure relief shall be incorporated in the basic design of the enclosures as a precaution against explosion in the event of an internal arc fault. Pressure relief shall be by means of bursting discs with deflection devices to ensure that personnel who may be present will not be endangered.
Circuit breakers shall be of 3-phase SF6 gas insulated for 132 kV switchgear with the arc quenching medium being SF6 gas.
All circuit breakers shall be electrically operated but shall also be fitted with independent mechanical manual operating mechanisms. The actual operation of the manual closing mechanism shall be independent of the force applied by the operator. Partial operation of the circuit breaker shall not be possible. The mechanical closing mechanism shall be protected against inadvertent operation.
The circuit breakers shall be suitable for auto reclose duty. Anti-pumping devices shall be included to prevent “pumping actions” of the mechanism.
Operation mechanism shall be of stored energy motor spring charged type with provision for manual spring charge. Operating handles shall be provided. The capacity of the energy storage system shall be large enough to permit operations as specified in the data sheets. They shall be automatically re-charged immediately following their closing duty and shall have a maximum charging time of 25s.
2.3.3 High Voltage Switchgear up to 52 kV
2.3.3.1
2.3.3.2
Switchgear shall comply with IEC 62271-200 and Project Specification RLNG-000-EL-SP- 0008.
HV switchgear shall be type tested metal enclosed ‘factory-built assembly’ with vacuum or SF6 circuit breakers. Vacuum Circuit Breakers will be used for 6.6 kV and 11 kV Systems.
2.3.3.3
HV switchgear should normally have 2x100 % rated bus sections.
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2.3.3.4
2.3.3.5
2.3.3.6
2.3.3.7
2.3.3.8
2.3.3.9
HV switchgear shall have rated short circuit withstand duration of a minimum of 1 sec.
In general, circuit breaker ratings shall be based on natural cooling, limited to a maximum of 4000 A.
Circuit breakers in the switchgear assembly shall normally be installed in single high formation.
Switchgear in the Train Substations shall be provided with one equipped spare circuit breaker. Switchgear outside of Train Substations shall be provided with one equipped spare circuit breaker and future floor space for one tier to be added on each end.
Motor feeder units at 6.6 kV and 11 kV shall be installed in single tier formation.
Each breaker shall have a key-operated Local/Off/Remote selector switch, key removable only in the remote position, installed in the LV compartment. The following functions shall be included:
• Local:
a). Breaker, isolator, earthing switch can be operated locally only for distribution feeders. b). Breaker, isolator, earthing switch can be operated locally in test position only.
• Off: breaker, isolator and earthing switch cannot be operated electrically. • Remote: breaker and isolator can only be operated from the ECMS.
2.3.3.10
Breaker/ Isolator/ Earthing switch ON/OFF control switches separate from bay control unit shall be provided.
2.3.4 Low Voltage Switchgear and MCC
2.3.4.1
2.3.4.2
2.3.4.3
2.3.4.4
2.3.4.5
2.3.4.6
Switchgear shall comply with IEC 60947, IEC 61439 and Project Specification RLNG-000- EL-SP-0009. It shall be Front access and Type tested inline with relevant IEC standards.
The switchgear and controlgear shall be designed to facilitate inspection, cleaning, maintenance and repairs.
The switchgear and controlgear shall be robust construction and shall be unaffected in part or whole by the forces imposed by short circuit or other fault currents, operation, vibration or temperature changes.
The degree of protection of the enclosure shall be at least IP 41 as specified in IEC 60529. The top of the switchgear shall be sealed to such an extent that the ingress of dripping water is prevented.
Switchgear shall be of the metal-clad compartmentalized type, Form 4B in accordance with IEC, and shall be designed to minimize any risk of developing or propagating a short circuit. The design shall also be such as to ensure personnel and operational safety during all operating conditions, inspections and maintenance.
The circuit breakers shall be provisioned with manual transfer functionality. The MCC shall be provided with a Trip Selector Switch which can be selected to trip any of the incomers or the bus-coupler upon actuation of the manual transfer command. Whenever required, the operator shall be able to initiate a manual bus transfer by selecting manual in the Auto/Manual switch and after selection of the required breaker intended to trip. The manual
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2.3.4.7
2.3.4.8
2.3.4.9
2.3.4.10
2.3.4.11
2.3.5 Motors
2.3.5.1
2.3.5.2
2.3.5.3
2.3.5.3
2.3.5.4
2.3.5.5
2.3.5.6
2.3.5.7
2.3.5.8
2.3.5.9
transfer’s initiation shall be through the closing command to the breaker that is intended to be closed. Before closing signal shall be routed through synchro-check signals. In case of manual transfer the intended breaker will first close and the selected breaker will trip.
Circuit breakers shall have anti-pumping features and manually reset lockout devices to prevent circuit breakers from re-closing.
Bus bars shall be housed in a separate compartment and shall be clearly marked with their respective phase colours. For the arrangement of bus bars, the phase sequence shall be L1-L2-L3 with phase L2 in the centre and phase L1 on the left, front or top while facing the equipment from the operating side.
Switchgear and Control gear shall be provided with maintenance mode to reduce the impact of arc flash hazards.
Type 2 coordination shall be provided for outgoing feeders of the LV switchgear.
LV switchgear incomer and outgoing ACB feeders shall have Multi-Functional Protection Relay. Motor starter shall have intelligent motor protection relay. For non-motor feeder shall be as shown single line diagram.
Motors rated <15 MW shall generally be squirrel cage induction. Synchronous motors should be considered for motors rated 15 MW and above. Synchronous motors may be specified for motors rated below 15 MW if justified by a cost benefit analysis approved by COMPANY.
All motors shall be rated for continuous operation at full load, with class F insulation and temperature rise limited to class B, unless otherwise specified in Motor datasheet. Motors shall be designed for full service voltage with applicable voltage drop defined in Cable selection and sizing philosophy, RLNG-000-EL-SP-5103.
Motors shall be certified or suitable for the hazardous area classification as per area classification drawing.
Motor internal parts shall be non-sparking.
Motors shall be high efficiency types as per IEC 60034 and shall be as specified in the Motor Datasheet.
Partial discharge monitoring: HV motors including generators 11 kV and above shall be provided with winding partial discharge monitoring sensors located within the main terminal box.
Wiring from couplers shall be terminated in a terminal box on the motor frame.
Motor Space Heater shall be provided for ratings 37 kW and above.
Cryogenic applications motors for LNG in-tank motors shall have under-power or undercurrent protection.
In general, a control station for electrically driven motors consisting of LOR (Local-Off- Remote) selector switch with Locking facility at all position and shall be located near the motor. The motor shall be controlled by the ICSS (normally) or Local PLC panel and by local switch (for maintenance testing). All motor starters shall be supplied with locking capability for attaching pad locks for positive isolation of the connected load(s). In general, for local control station requirement and its type, respective P&ID’s shall be referred.
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2.3.5.10
2.3.5.11
Likewise, transfer pumps and the like (respective P&ID’s to be referred), shall have Start- Stop Pushbutton located near the pump.
Motor Control Station shall be of Ingress Protection IP66 and suitable for hazardous areas installation.
2.3.5.12
Motor Operated Valves (MOV) shall be provided with local Isolation.
2.3.6 Capacitors and Filters
a) HV capacitors shall comply with IEC 60871.
b) HV capacitor banks shall be installed outdoors in a suitable containerised metallic enclosure with
necessary door interlocks.
c) Capacitors shall be of the low loss, metal enclosed, hermetically sealed type.
d) All capacitor units shall have individually fused elements.
e) Where necessary, the capacitor inrush current shall be limited by:
• Contactors with pre charging resistors. • Serial air coils.
f) Discharge resistors shall be provided to reduce the voltage to 50 V within 60 sec for low voltage and
within 5 minutes for high voltage capacitors.
g) An interlock system shall be provided for all automatically controlled capacitor banks to prevent re-
energisation, when the residual voltage is above 10 % Un.
h) Unless otherwise specified, the capacitor stages shall be switched automatically. Time-delay device shall be used for switching on and off the capacitor stages to prevent unnecessary operation of the controller for momentary signal changes.
2.4
Electrical Protection and Control System
2.4.1 General
The selection and application of protective relays are discussed in the following paragraphs. These relays protect equipment in the Auxiliary Power Supply System, Generator Terminal Systems, 132kV System, Turbine-Generator System, and the electrical loads powered from these systems.
For protection and control for power interfaces with TRANSCO, TRANSCO specifications and requirement shall be followed.
Capacitor banks for power factor correction shall be connected at all 11kV bus in a 2x50% configuration. The electrical system study will check power factor requirement at 132kV PCC is maintained during one capacitor bank failure scenario.
The protective relaying system will be a coordinated application of individual relays. For each monitored abnormal condition, there will be a designated primary device for detection of that condition. A failure of any primary relay will result in the action of a secondary, overlapping scheme if possible, to detect the effect of the same abnormal occurrence. The secondary relay may be the primary relay for a different abnormal condition. Alternate relays may exist which detect the initial abnormal condition, but which have an inherent
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time delay so that the alternate relays will operate after the primary and secondary relays. Similar to secondary relays, the alternate relays may be primary relays for other abnormal conditions. All protective relays will be selected to coordinate with protective devices supplied by suppliers of major items and the thermal limits of electrical equipment, such as feeders, transformers and motors.
Secondary current produced by current transformers will be in the 1 ampere or 5 ampere range, and voltage signals produced by metering and protection potential transformers will be in the 110 volt range.
Protective relay packages will be provided to minimize effects from faults and malfunctions. The protection will be provided by a multi-function relay.
The protective relaying scheme will be designed to remove or alarm any of the following abnormal occurrences or similar events.
2.4.2 132kV Gas Insulated Switchgear
2.4.2.1
132kV Incomers
The 132kV Incomer shall be protected against the effects of the following:
•
•
•
•
•
•
•
•
•
(25)
Synchro-check
(27)
Undervoltage
(50)
Instantaneous Overcurrent
(50N)
Instantaneous Overcurrent Earth Fault (Residual)
(51)
Inverse time Overcurrent
(51N) Time delay zero sequence Overcurrent Fault
(59) Overvoltage
(60)
Voltage/ Current Balance
(87)
Differential
2.4.2.2
132kV Bus-Couplers and Sectionaliser
The 132kV Bus-coupler shall be protected against the effects of the following:
•
•
•
•
•
•
(25)
Synchro-check
(27)
Undervoltage
(50)
Instantaneous Overcurrent
(51)
Inverse time Overcurrent
(59) Overvoltage
(87B) Busbar Differential
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2.4.2.3
132kV Outgoing Feeders
The 132kV Outgoing feeders shall be protected against the effects of the following:
•
•
•
•
•
•
•
(27)
Undervoltage
(50)
Instantaneous Overcurrent
(50N)
Instantaneous Overcurrent Earth Fault (Residual)
(51)
Inverse time Overcurrent
(51N) Time delay zero sequence Overcurrent Fault
(59) Overvoltage
(87L) Line Differential
2.4.3 HV/HV Power Transformer Relays (132kV/11.5kV, 11kV/6.9V)
Power Distribution Transformers:
The distribution power transformers are protected against the effects of the following conditions:
•
•
•
•
•
•
•
•
•
(51)
Inverse definite minimum time overcurrent protection (IDMT)
(50)
Instantaneous overcurrent protection
(67)
Directional overcurrent protection (for parallel feeders)
(51N)
Inverse definite time residual earth fault protection (IDMT)
(50N)
Instantaneous residual earth fault protection
(67N) Directional residual earth fault protection (for parallel feeders)
(51G) Earth fault protection (NOTE 3)
(87T) Transformer differential protection (for 5MVA and above)
(64R) Restricted earth fault protection
This protection will be provided by the relays which are discussed in the following paragraphs.
The HV breaker feeding the transformer will have primary and back-up line differential intelligent electronic device (IED) which can provide line differential (87L), distance zones (21), instantaneous/time overcurrent (50N/51N) protection for the HV cable and associated transformer.
A rapid increase in pressure within the transformer tank associated with an internal fault will be detected by a sudden-pressure relay, Device 63. This relay will be furnished with the transformer. Low cooling insulating oil level and high oil temperature will be monitored and alarmed.
NOTE 3: Separate Numerical relay with IEC 61850 communication feature shall be considered for all back- up earth fault (51G or 50G) protection, Winding and Oil Temperature, Buchholz, oil level, etc for the transformer incomers at different voltage levels.
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2.4.4 6.6 kV and 11 kV Metal Clad Switchgear
The High voltage switchgears will be protected by their incoming main and tie breakers having multi-function relay with time overcurrent (Device 51), time earth overcurrent (51G) and a separate bus differential (87B) relay for phase protection, earth fault protection, synchro-check (25), undervoltage (27), overvoltage (59), Directional overcurrent (67), Directional residual earth fault (67N) protection.
The High Voltage Ring Main Unit (RMU) shall be provided with On Load Disconnecting Switch in the incomers (Ring Network). Outgoing transformer feeder will be protected by breaker having multifunction relay.
2.4.4.1
HV Motors – Induction Motor
The HV motors will be protected against the effects of the following:
•
•
•
•
•
•
•
•
•
•
•
•
•
(27)
Undervoltage
(37)
Undercurrent for submersible motors
(46)
Reverse Phase/ Phase Balance
(47)
Phase Sequence
(49)
Thermal Overload
(49T) RTD Biased Thermal Overload
(50)
Instantaneous Overcurrent
(50N)
Instantaneous residual earth fault protection
(51LR) Locked Rotor
(59) Overvoltage
(60)
Voltage/ Current Balance
(66)
Starts per Hour
(87)
Differential (> 3500kW)
2.4.4.2
HV Motors – Synchronous Motor
The HV Synchronous motors shall be protected against the effects of the following:
•
•
•
•
•
•
(25)
Synchro-check
(27)
Undervoltage
(40) Field Relay / Loss of Excitation
(49)
Thermal Overload
(49)
RTD Biased Thermal Overload
(50)
Instantaneous Overcurrent
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•
•
•
•
•
(50N)
Instantaneous residual earth fault protection
(51)
Inverse Time Overcurrent
(51N)
Inverse definite time residual earth fault protection
(59) Overvoltage
(87)
Differential
2.4.4.3
HV Motors – ASD fed
The HV motors- ASD fed shall be protected against the effects of the following:
•
•
•
•
•
•
•
•
•
•
•
(27)
Undervoltage
(47)
Phase Sequence
(49)
Thermal Overload
(50)
Instantaneous Overcurrent
(50N)
Instantaneous residual earth fault protection
(51LR) Locked Rotor
(51)
Inverse Time Overcurrent
(51N)
Inverse definite time residual earth fault protection (IDMT)
(58) Rectification Failure Relay
(59G) Ground Overvoltage Relay
(87)
Differential (above 3500kW)
2.4.4.4
HV Outgoing Feeder
The HV Feeder will be protected against the effects of the following:
(51)
Inverse definite minimum time overcurrent protection (IDMT)
(50)
Instantaneous overcurrent protection
(51N)
Inverse definite time residual earth fault protection (IDMT)
(50N)
Instantaneous residual earth fault protection
(51G) Earth fault protection
(87L) Cable differential protection (As applicable for inter sub-station long cable)
•
•
•
•
•
•
2.4.4.5
Capacitor Banks & Harmonic Filters
The Capacitor Banks & Harmonic Filters shall be protected against the effects of the following:
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•
•
•
•
•
•
(27)
Undervoltage
(46)
Reverse Phase/ Phase Balance
(50)
Instantaneous Overcurrent
(51)
Inverse definite minimum time overcurrent protection (IDMT)
(51G) Earth Fault protection
(59) Overvoltage
2.4.5 690 & 415 Volt Switchgear
The low voltage switchgear will be protected by their incoming electrically operated (E.O.) main and tie breakers having integral microprocessor based breaker overcurrent trip system. Switchgears shall have multi-function relay with time overcurrent (Device 51), time earth overcurrent (51G), (67) Directional overcurrent and (67N) Directional residual earth fault protection. The feeder breakers will be provided with multi-function relay to protect supply cable and individual loads. Included devices are time/instantaneous overcurrent (50/51) and time/instantaneous neutral overcurrent (50N/51N). Motor feeder shall have the following protection:
•
•
•
•
•
•
•
•
(27)
Undervoltage (where specified)
(46)
Reverse Phase/ Phase Balance
(49)
Thermal Overload
(50)
Instantaneous Overcurrent
(51)
Inverse Time Overcurrent
(51G) Earth Fault protection
(59) Overvoltage (where specified)
(51LR) Locked Rotor
2.4.6 Emergency Diesel Generator
The Emergency Generator will be protected against the effects of the following:
•
•
•
•
•
•
(12)
Overspeed
(15) Frequency matching
(25)
(27)
(50)
(51)
Synchronism check
Undervoltage
Instantaneous Overcurrent
Inverse Time Overcurrent
•
Voltage Restrained Overcurrent The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party. .
(51V)
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•
•
•
•
•
•
(51N/50N)
Residual Earth Fault
(51G)
(59)
Neutral Earth Fault
Overvoltage
(32) Directional Power
(67) Directional Overcurrent
(67N) Directional residual earth fault protection
2.5
Substation
The Substation Building shall consist of the following rooms but not limited to the following:
• ECMS equipment room (if necessary). • Electrical equipment room. • GIS switchgear room. • ASD room (if necessary). • Battery room. • HVAC room. • Transformer bays (outdoor).
All substation penetrations shall be from side or bottom and not from roof however if required equipment can be placed on the roof.
2.5.1 ECMS Equipment Room
2.5.1.1
In general, ECMS room shall not be provided, and the equipment shall be housed in electrical equipment room.
2.5.1.2
ECMS equipment will house the ECMS cabinets and operator consoles.
2.5.2 Electrical Equipment Room
2.5.2.1
2.5.2.2
2.5.2.3
2.5.2.4
Electrical equipment room shall accommodate LV and HV air insulated switchgear, UPS’s, thyristor control panels, distribution boards, electrical control panels, Interposing relay panel and HV and LV ASDs unless a dedicated room is necessary for large ASD’s.
Space shall be allocated for testing of LV MCC control units, HV/LV circuit breaker trolleys, cabinets for drawing / documents, notice boards, lockout box for padlocks and keys for isolators etc.
Arc flash zones around equipment shall be calculated and marked on the floor of the substation. Notices explaining the level of personal protective equipment required in the area shall be posted at the entrance to the substation.
Suitably rated rubber mats shall be provided in front of Switchgear and MCC’s for their entire length.
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2.5.2.5
HV capacitors with switched banks will be located outdoors with power factor controller/ panel inside the air conditioned enclosure housing the capacitors.
2.5.3 GIS Switchgear Room
2.5.3.1
Gas Insulated Switchgear shall be installed in a dedicated room and auxiliary equipment related to the GIS, e.g Protection Relay Panels and Remote Control Panels shall be installed in a separate room (away from GIS room). However, Local Control Cubicle (LCC) shall be installed separately within the GIS room. LCC shall be supplied as a separate cubicle. Crane shall be provided in the GIS room for the Switchgear maintenance activity. The minimum crane capacity shall be inline with the heaviest GIS parts that shall be required to be handle.
2.5.3.2. Detection and monitoring of SF6 release in the room shall be provided if required from the
environmental point of view.
2.5.3.3
Warning plates shall be provided outside the building, instructing personnel not to enter without personal protection when the alarm display is ‘on’.
2.5.4 ASD Room
2.5.4.1
In general, no separate room shall be used for placing the Adjustable Speed Drives and shall further be evaluated for HV ASD with water-cooling.
2.5.4.2
Considerations shall be made for easy access and maintainability of the ASD systems.
2.5.5 Battery Room
2.5.5.1
Separate battery room shall be provided.
2.5.6 HVAC Room
2.5.6.1
2.5.6.2
Complete HVAC system shall be configured to provide 100% redundancy e.g. Chillers/ Condensing units, AHU.
HVAC plant/ equipment shall be located within a separate room within the substation with external access or in a dedicated room/ building adjacent to the substation.
2.5.7 Transformer Bays
2.5.7.1 Fences around all outdoor Transformers shall be provided.
2.5.7.2
2.5.7.3
2.5.7.4
2.5.7.5
Oil Filled Transformer shall have a firewall with 2 hours rating as per NFPA 850.
Removable Roofs above outdoor transformers shall be provided.
Transformers fitted with liquid immersed OLTC, shall be provided clearance above to allow un- tanking of the OLTC.
Oil collection pit shall be designed as per sec 4.7 of RLNG-000-PR-PP-0001, Drainage Philosophy.
2.5.7.6 Minimum 1000 mm clearances shall be provided all around the transformer and any neutral
earthing resistor bank. NERs shall be located adjacent to the associated transformer.
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2.6
Earthing and Lightning Protection System
2.6.1 General
2.6.1.1
2.6.1.2
2.6.1.3
2.6.1.4
2.6.1.5
An earthing and bonding system will be provided throughout the plant area.
The Substation Building earthing system shall include perimeter loop earth conductor installed at least one metre away from building foundations. High Voltage Indoor GIS Substations shall be provided with embedded earthing meshes acting as High Frequency earthing grids with connection points or pins in the Substation Floor as per GIS Manufacturers recommendations.
Earthing and bonding for electrical power distribution system will be designed and installed in accordance with IEC 60364 and IEC 61936.
IEEE 80 shall be used for design of earthing system of the incoming power outdoor substations.
A separate earthing system shall be provided for the instrumentation earthing systems. Unless otherwise specified dual redundant earth bars for each of the earthing system as below shall be provided in the substations and switch room.
i. Intrinsically safe instrument earth bar.
ii. Instrument earth bar. iii. Safety electrical system earth bar.
2.6.1.6
The earthing system is intended to provide the following protection:
• An electrical path from equipment to earth for personnel protection in the event that
live conductors become earthed to equipment.
• An electrical path to earth for static and lightning discharge protection
• A backup electrical path from equipment to system neutral for equipment and
system protection in the event that live conductors become earthed
2.6.1.7
2.6.1.8
The earthing system may include earth rods, static wires on overhead pole lines, main earth cables, earth buses, branch conductors and connectors.
The earthing system design shall include the following earth rod type assemblies to be installed in earth:
• Test well type with accessible bolted connector, pipe encasement and cover • Earth rod with heavy-duty connector without encasement and cover.
2.6.1.9
A test well type earth rod shall be provided as follows:
•
In paved areas, not accessible to vehicular traffic
2.6.1.10
2.6.1.11
Main earth/bonding cables shall be connected to earth bus assemblies by an In and Out fashion, with equipment earth taps connected to main cable between bus assemblies, which will allow disconnecting main cables at ends, for testing as follows:
• Checking continuity of earth loops
Complete earth loops with cables, rods, earth buses, taps, etc., shall be provided at the following:
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• Substations, buildings, i.e., prefabricated building, site erected buildings. • Process and equipment areas • Earth loops shall interconnect except for those in isolated area • LNG Tanks
2.6.1.12
Individual earth rods will be adequate when the following are isolated from other equipment:
• Electrical power poles • Electrical floodlight poles • Columns of pipe racks or pipe sleepers • Non process equipment located remote from process area
Earth cables are to be installed underground direct buried and shall not be installed less than 500 mm minimum below grade.
The neutral conductor between power transformers and earthing resistors shall be sized as required and installed in a protective raceway:
Earth connection points embedded in concrete floor shall be located beneath equipment in substations and switch houses as follows:
• At each end of switchgear and motor control centre line-ups • At small transformers, panel boards, control panels and other electrical equipment
Earthing connections above floor shall be connected with earth cable to equipment earth buses, neutrals and electrical enclosures.
Earth cable emerging from underground or concrete shall be protected with heavy wall PVC conduit projecting a minimum of 150mm above grade or concrete.
Each metallic pole or cross arm shall be earthed to the earth rod.
Metallic cable trays and conduit systems shall be electrically continuous to metallic supporting members and to earth throughout their length.
Bonding jumpers shall be used at tray and conduit expansion joints.
Fence shall be earthed at regular intervals, maximum 50 m for site boundary and 25m for internal plant fences and shall be by means of Earth Electrodes directly connected only where nearest plant earth grid is not available .
To protect against lightning-induced currents, it may become necessary to install a separate earthing conductor, known as PEC, along cables in trenches. PECs shall be bonded to the above ground cable ladder racks and supports. The number of PECs shall be determined as part of an EMC assessment, considering the number of cables, the transfer impedance of the cables, the expected lightning current, trench width, and the allowable transient voltage.
Cross section of earthing conductors shall be standardised during project execution stage.
Earthing conductors shall be insulated when routed above ground. Earthing conductor shall be of stranded annealed copper conductor with 750 V grade green / yellow PVC insulation for electrical earth, and green PVC insulation for instrument earth.
2.6.1.13
2.6.1.14
2.6.1.15
2.6.1.16
2.6.1.17
2.6.1.18
2.6.1.19
2.6.1.20
2.6.1.21
2.6.1.22
2.6.1.23
2.6.1.24
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2.6.1.25
2.6.1.26
The minimum size of earth bars shall be 50x6 mm. Substation earth bus shall be continuous interior bar around the entire perimeter and connected to the exterior earth bar/grid.
For further details please refer “Philosophy for Earthing, Bonding, and Lightning Protection, RLNG-000-EL-SP-5101”.
2.6.2 Earth Grid Design
2.6.2.1
2.6.2.2
2.6.2.3
2.6.2.4
2.6.2.5
2.6.2.6
2.6.2.7
2.6.2.8 2.6.2.9
2.6.2.10
2.6.2.11
The earthing system shall be designed on the ring principle with interconnecting conductors as necessary. This ring shall be connected to the earth well or electrodes. Earthing grids of various substations and plant units within the plant shall be interconnected.
Soil resistivity measurements shall be made as part of the geotechnical survey.
Based on the soil resistivity, an earth electrode design shall be carried out to optimise the location and number of electrodes to meet the resistance to earth requirements. Calculations of touch and step voltages for both electrical fault and lightning strike conditions shall be carried out using the actual soil resistivity and surface materials. Distances between rods shall be greater than their depth. A minimum separation of the order of 3 m shall be considered. At least one more than the required minimum number of electrodes shall be installed.
Whenever possible, earth electrode shall be installed deep enough to reach water table or permanent moisture level, and deep enough to reach stable ground conditions.
Bentonite or similar material may be used to improve contact efficiency in difficult ground conditions.
For the earthing of electrical systems, equipment and structures, each installation shall have one common earth grid connected to at least two groups of earth electrodes.
Connection between earth electrode and earth cable shall be arranged in a pit with cover to allow maintenance and testing. Minimum Earth bonding conductor size shall be 4mm. Earth Bars shall be provided with test link facility to enable testing without compromising the system. As a minimum two earthing bosses shall be provided at diagonally opposite locations on skid mounted equipment. Electrical shall maintain an overview of all earthing requirements.
2.6.3 Earth Electrodes
The earthing system will consist of earth electrodes interconnected by buried bare copper cabling. Where present at a building or structure served, each of the following electrodes shall be used as part of the earthing system.
• Metal Underground Water Pipe • Metal Frame of the Building or Structure • Concrete-Encased Electrode • Earth Ring • Rod and Pipe Electrodes
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• Other Listed Electrodes • Plate Electrodes
For Concrete-Encased Electrodes, “building or structure served” is a foundation that includes a structure such as a building or shelter. For the case of a piece of equipment such as a pump sitting on a foundation, the equipment is being served and not the structure. Therefore, this foundation does not require the bonding of the concrete-encased electrode. If the structure includes small power accessories such as light fixtures or receptacles and is at least partially enclosed by walls or a roof, this structure is considered as served and does require the bonding of the concrete-encased electrodes.
Earth electrodes of the following types shall be used:
• 50 mm diameter 3.5 m long hot dip galvanised steel pipes minimum thickness 3 mm. • 19 mm diameter copper bonded steel rods with copper cladding minimum thickness of 250
microns.
Deep earth well if needed to meet desired earthing resistance shall also be considered.
2.6.4 Resistance to Earth
2.6.4.1
2.6.4.2
The resistance of all electrodes connected to the main earth grid shall not exceed 1 ohm.
The combined resistance to the general mass of earth of the electrodes provided for lightning protection shall not exceed 10 ohms when isolated from the plant earth grid.
2.6.4.3
The individual earth electrode resistance shall not exceed 25 Ohms.
2.6.4.4
Instrument clean earth bar shall be connected to a group of earth electrodes to obtain a resistance not exceeding 1Ω. Minimum distance between these earth electrodes and electrical system earth electrodes shall be 5m.
2.6.5 Equipment to be earthed and bonded to the plant earthing/bonding system
2.6.5.1 All electrical equipment enclosures not necessarily limited to the following:
• Motors • Starters • Motor Control Centres • Switchgear • Transformers • • Lighting Poles • Panel boards • Process pump bases, vessels, tanks, pipe rack supports • Receptacles and Outlets • Transformer neutral when and in manner indicated.
Instrument Control Panels and Junction Boxes
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• Wire fences or other metallic enclosures in vicinity of electrical lines or electrical apparatus
(outdoor HV substations).
• Vessels containing flammable liquids or gasses unless directly supported by earthed steel
members.
• Vertical vessels higher than 6m in equipment areas, all isolated vertical vessels, storage
tanks, flare stacks, etc. (two connections required) per Protection Standard.
• Storage tanks at the specified intervals as identified on vessel drawings. • Columns on pipe racks and pipe sleepers at the specified intervals of 50m. (maximum). • Electrical power poles as specified.
2.6.5.2
2.6.5.3
Truck loading racks for hazardous materials, all structures, loading pipes and tracks shall be permanently connected to an earthing system.
Wherever filling operations of flammable material are performed, the loading pipe and container shall be provided with means of connecting to earth. Earthing connections shall be provided around every swing joint. Note: Ships are isolated from facility per sigto requirements
2.6.5.4
Earth cable reels shall be provided for mobile equipment with continuity monitors.
2.7
Lighting And Sockets Outlets
It shall be captured and validated, the minimum requirements and objectives for light pollution and on environmental impact to wildlife.
Light fittings shall have easy access not requiring scaffolding were practicable.
The lighting system shall consist of the following:
2.7.1 Normal Lighting:
2.7.1.1
2.7.1.2
Normal lighting is supplied from main power supply.
The lighting design and illumination levels shall be in accordance with BS EN 12464-1 & 2.
2.7.2 Emergency Lighting:
Emergency lighting is same as normal lighting except that it powered from emergency generator.
The minimum number of emergency luminaires in relation to the total number of luminaires shall be determined as follows:
• Utility area -20 % • Process area -10 % • Other building / offices- 20% • Control building and auxiliary rooms -50 %
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• Substations, Compressor / Pumps Shed, field auxiliary rooms, compressor and generator
buildings -30 %.
• Fire water pump area- 30% • 20% of General and flood lighting fixture shall be part of emergency lighting system. • 20% of street and fence floodlight fixture shall be part of emergency lighting system. •
In remote area, where only a limited number of fitting are required, 50% of battery back-up (180 minutes autonomy time) lighting fittings shall be used ETR/ITR).
2.7.3 Escape Lighting:
2.7.3.1
2.7.3.2
2.7.3.3
2.7.3.4
Escape lighting is supplied from emergency generator with integral battery backup for 90 minutes.
The emergency and escape lighting shall be provided as defined in BS EN 1838.
As a minimum, 30% of the total Emergency (Escape) lighting in any area shall be battery backed-up. Final quantity shall be govern inline with HSE requirement/ philosophy.
All Exit sign light fixtures used for escape during emergency situations shall be LED type with integral battery backup suitable for maintaining a lux level of 1 lux.
2.7.3.5
The detail requirement of escape lighting for building shall refer to local regulation.
2.7.4 Distribution Boards
2.7.4.1
2.7.4.2
Lighting and small power systems including heat tracing and MOVs shall be supplied from 415 V, TP&N, 4 wire, Main distribution boards located inside respective substation building.
Incoming power supply for the plant/ field distribution panel shall be by using four pole MCCB for three phase and two pole MCCB for single-phase boards.
2.7.4.3
The Main distribution boards shall consist of outgoing circuits as below.
• Four pole MCBs or MCCBs for three phase feeders supplying power to a sub distribution
board.
• Three pole RCCB supplying power directly to three phase load • Three pole MCCB supplying power to MOVs • Two pole RCCB for single phase L-N feeders and for L-L 415 V feeders
2.7.4.4
Each RCCB shall be equipped with the following.
• 30 mA earth leakage protection for small power feeders & 100 mA for lighting feeders • Auxiliary contacts for ‘tripped’ and status indication • Padlocking facility.
2.7.4.5
No more than five socket outlets shall be wired to one circuit.
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2.7.4.6
2.7.4.7
2.7.4.8
2.7.4.9
One group alarm for each distribution board shall be sent to ECMS to indicate outgoing MCBs tripped status along with alarm for Incomer MCCB. Incoming MCCB open/closed status for each distribution board shall be sent to ECMS.
Distribution boards shall be supplied with copper busbars, unless otherwise specified in requisition or datasheet.
Total lighting fixture load per circuit shall be limited to 2.0 kW. For plant/ field distribution panel, branch circuits loading shall not exceed 80 % of rating of branch circuit protective device rating.
Each distribution board & panel shall incorporate 20 % equipped spare ways to allow for future growth.
2.7.5 Luminaire Types
2.7.5.1
2.7.5.2
LED light shall be used and in case of non-availability for specific application or range, energy saving type should be used.
Industrial type LED luminaires shall be used for illumination in substations, control rooms, offices.
2.7.5.3
Indoor luminaires shall be IP 51 and outdoor IP 66.
2.7.6 Lighting Control
2.7.6.1
2.7.6.2
2.7.6.3
2.7.6.4
2.7.6.5
2.7.6.6
All outdoor plant lighting, street lighting, fence lighting and flood lighting shall be controllable by photo electric cells.
All outdoor plant emergency lighting shall be controlled by photo electric cells fed from the same emergency supply.
Normal lighting in industrial and non-industrial buildings shall be controlled by infra-red occupancy detectors.
It shall be possible to manually switch on the lighting by over-riding the Infra-red detectors and timers.
Lighting specifically installed for gauge glass illumination shall be controlled by a locally mounted switch.
Lighting installation in control rooms shall be designed for switching off independently ceiling light groups to suit operator needs. Dimmers shall be provided to control the illumination level. The reflectors on the luminaires shall be such as to provide glare free light with high degree of visual comfort on VDU screens.
2.7.7 Illumination Levels
Illumination level (average lux) shall be as per below tables. For areas not covered by below tables recommendation from latest Section 5 of the latest edition of BS EN 12464-1 and 2 shall be used.
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Table #2: For Indoor Lighting Illumination Levels
BS EN 12464-1 Table Ref
Type of area / task / activity
Maintained illuminance Ēm (Lux)
100
200
300
200
500
200
150
200
500
Specific Requirements (EN Standard) Requires enhanced contrast on the steps.
100
150
Canteen: 100 Lux
Gym
Toilets and locker rooms
First aid room
Switch rooms, including relay and auxiliary rooms Warehouse bulk storage: 50 Lux Outdoor storage areas: 5 Lux
150
Vertical illuminance, portable lighting may be used. Laboratories and analyser rooms
100
Local on workbenches and machine tools: 400 Lux
5.1.2
5.1.3
5.1.4
5.2.1
5.2.3
5.2.4
5.2.6
5.3.1
Stairs
Elevators, lifts
Loading ramps/bays
Canteens, pantries
Rooms for physical exercise Cloakrooms, washrooms, bathrooms, Rooms for medical attention Plant rooms, switch gear rooms
5.4.1
Store and stockrooms
Control stations
Storage rack face
Precision measuring rooms, laboratories Boiler house
5.5.3
5.5.4
5.10.4
5.20.2
5.20.3
5.20.4
Machine halls
200
Side rooms, e.g. pump rooms, condenser rooms, etc.; switchboards (inside buildings)
200
Plant rooms, battery room
5.20.5
Control rooms
500
5.26.2
Office Writing, typing, reading, data processing
Rear of panels: 150 Lux Auxiliary rooms: 300 Lux Outside, near entrances: 150 Lux Instrument room and telecom room: 500 Lux
500
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BS EN 12464-1 Table Ref
Type of area / task / activity
Maintained illuminance Ēm (Lux)
Specific Requirements (EN Standard)
5.26.4
5.26.5
5.26.6
5.29.2
5.33.2
CAD workstations
Conference and meeting rooms
Reception desk
Kitchen
Libraries, reading rooms
500
500
200
500
Gate house, reception area Catering areas (food preparation and serving)
500
Table #3: For Outdoor Lighting Illumination Levels
BS EN 12464-2 Table Ref
Type of area/ task/ activity
Maintained illuminance Ēm (Lux)
5.1.1
Walkways exclusively for pedestrians
5.1.2
5.8.2
5.8.3
5.9.1
5.10.1
5.10.2
Traffic areas for slowly moving vehicles (max. 10 km/h), e.g. bicycles, trucks and excavators
Ladders, stairs, walkways
Offshore boat landing areas / transport areas Light traffic, e.g. parking areas of shops, terraced and apartment houses; cycle parks Remote-operated processing installations Processing installations with
Specific Requirements (EN Standard)
Non-operational areas with limited attendance, e.g. tank farms without equipment requiring regular operator intervention: 0.5 Lux Fence lighting: 0.5 Lux Road lighting: 5 Lux
Plant and jetty approaches and road intersections Road lighting
walkways, platforms, stairways, ladders, module roofs (offshore)
100
5
10
100 (25)
5
Car parks: 1 Lux
50
150
Safety colours shall be recognisable. General plant area Operating areas requiring regular operator
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BS EN 12464-2 Table Ref
Type of area/ task/ activity
Maintained illuminance Ēm (Lux)
limited manual intervention
5.11.4
General servicing work and reading of instruments
5.1.4
Pedestrian passages
100
50
Specific Requirements (EN Standard)
intervention such as pumps, compressors, generators, drivers, valves, manifolds, loading arms, etc. Where possible level gauges and instruments to have integral lighting or be lit from single light Mustering area
2.7.8 Floodlights and Street Lights
2.7.8.1
2.7.8.2
LED Floodlights shall be utilized for general area lighting as much as practical and shall be coordinated with other lighting systems to avoid duplicate lighting. Wherever possible Floodlights shall be installed on existing structure, fin fan coolers structure and as such.
In general, street lighting shall be provided along street. Where the lighting does not provide specific illumination levels, floodlights can be used in addition. Both street and area floodlights shall be on photocell control with manual on/off override.
2.7.9 Perimeter fence lighting.
2.7.9.1
2.7.9.2
2.7.9.3
The perimeter fence lighting shall be fed from emergency power supply.
Perimeter fence lighting shall be provided for the plant fencing with LED lamps on 6m high poles.
Each lighting pole shall include a fuse box as well as a four-pole terminating box for looping the feeder cable.
2.7.10 Aircraft Warning Lights
2.7.10.1
2.7.10.2
2.7.10.3
2.7.10.4
Aircraft warning lights shall be installed in accordance with local aviation regulations.
The warning light fixtures shall each consist of a double lamp unit with automatic changeover to the stand-by lamp upon failure of the operating lamp.
The lamp used for aircraft warning lights shall be of long-life type.
A facility shall be provided for lowering the luminaires for re-lamping.
2.7.11 Power Receptacles and Convenience Outlets
2.7.11.1
Convenience socket outlets located outdoors shall be switched 240 V, SP&N + E, 16 A, with spring flap cover. The outlets shall be located throughout the plant such that portable tools, hand lamps and test equipment can be supplied via a 25 m extension cable.
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2.7.11.2
2.7.11.3
2.7.11.4
4.7.11.5
The convenience receptacles shall be suitable for installation as per area classification drawings.
Welding socket outlets shall be supplied directly from the LV Distribution board. Welding outlets shall be 415 V, TP+N+E, 63 A, 5-pin switched outlets interlocked to prevent plug removal from a loaded circuit.
Welding socket outlets shall be installed at strategic locations throughout the plant such that equipment can be reached by a 50 m extension cable. The welding socket outlet circuits should not serve any other equipment and should not have more than three outlets connected per circuit.
Socket outlet circuits shall be protected by residual earth leakage circuit breaker (RCCB). The RCCB operating current shall be 30 mA for circuits of less than 125 A and 300 mA for circuits equal to or greater than 125 A.
2.8
Cabling and Cable Support System
2.8.1 General Requirements
2.8.1.1
2.8.1.2
2.8.1.3
2.8.1.4
2.8.1.5
2.8.1.6
2.8.1.7
Cables shall be in accordance with relevant IEC standards and Project Specification RLNG- 000-EL-SP-0006.
Power and control cables shall be of annealed stranded copper conductors, XLPE insulated, steel wire armoured, and overall PVC sheathed. Earthing cables shall be PVC sheathed, coloured yellow/green.
Armour for single core cables shall be of aluminium.
Single-core cables of a three-phase circuit shall be laid in trefoil formation, except in the case of short cable runs.
Single-core cables laid in trefoil formation, shall be braced by preformed non-magnetic cable cleats.
HV cables shall have conductor and insulation screen.
Lead sheath cables if required or equivalent eco-friendly sheathing shall be used subject to COMPANY approval for underground cables in hydrocarbon contaminated soil.
2.8.1.8
Fire resistant cables:
• Where fire resistant cables are specified, they shall comply with IEC 60331 and shall be zero
halogen low smoke type.
• Where fire-resistant properties are required for the above ground section of an underground cable, a proprietary fire proofing can be applied provided the above ground cable length does not exceed 10 % of the total length, with COMPANY approval.
2.8.1.9
Flame retardant cables
•
Flame retardant cables shall be installed in normally manned and indoor areas.
• Flame retardant cables shall conform to IEC 60332 with a minimum light transmission value of 60 % as per IEC 61034-2 and halogen gas emission of 0.5 % as per IEC 60754-1 and IEC 60754-2.
The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party. .
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2.8.1.10
2.8.1.11
2.8.1.12
2.8.1.13
At least 20 % spare cores shall be provided in control cables subject to a minimum of one core in each cable.
Cables glands shall be double compression type and ISO metric threaded type.
Cables glands for Hazardous Area shall be dual certified for Ex’db’ and Ex’eb’
Minimum cable size of 4.0 mm² for socket outlets and 2.5mm2 for lighting.
2.8.1.14 Cable cleats shall be certified for the applicable peak short circuit current. Cleats used for
single core cable shall be non-magnetic.
2.8.2 Underground Cable Installation
2.8.2.1
2.8.2.2
2.8.2.3
2.8.2.4
2.8.2.5
2.8.2.6
2.8.2.7
2.8.2.8
2.8.2.9
2.8.2.10
2.8.2.11
2.8.2.12
HV and MV primary distribution cables shall be directly buried with duct banks for road crossings.
Single core cables laid in trefoil formation shall be braced with non-magnetic cable clamps.
Cable joints shall not be used except with COMPANY approval where length and size of cable exceeds maximum manufacturing capability.
A list of all joints complete with the GPS coordinates, drawings, make and part number of the joint shall be provided.
In paved areas, concrete shall be coloured red over electric cable trenches.
HV cables in trenches shall be laid in single layer.
LV cables in trenches can be laid in two-layer formation.
Spacing between cable centres shall be as follows:
• Between HV cables: 300 mm.
• Between HV and LV cables: 300 mm.
• Between LV cables: 150 mm.
• Between LV power cables and instrument cables: 600 mm.
• Between HV power cables and instrument cables: 1000 mm.
Cable markers shall be installed along the cable route as per the standard drawings. For underground cables in unpaved areas, cable route markers shall be provided at every 25 m, at change of direction, and at both ends for road and pipeline crossing.
Due consideration shall be given to routing of power cables with respect to low energy instrument and control cables to avoid interference. A minimum separation of 1500 mm shall be allowed between long parallel power and low energy instrument and control cables. Additional separation of 4000 mm is required from high voltage cables. A vertical separation of 150 mm shall be provided for cables crossing at 90°.
Control cables shall be laid alongside their respective power cables.
Cables crossing roads shall be installed in concrete encased PVC pipes. At least 20 % spare pipes subject to a minimum of two shall be installed for future requirements. Bell mouths shall be installed and sealed at both ends.
The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party. .
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REVISION: 1
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2.8.3 Aboveground Cable Installation
2.8.3.1
2.8.3.2
2.8.3.3
2.8.3.4
2.8.3.5
2.8.3.6
2.8.3.7
2.8.3.8
2.8.3.9
2.8.3.10
Cable tray and ladder racks supported from structures shall be used for above ground cables.
Cable ladders shall be laid in horizontal formation supported at a distance of not more than 6 m, unless otherwise agreed.
Cable trays shall be typically supported every 1.5 m to 2 m and shall further be finalized based on Cable ladder vendor recommendation. Number of cables in the trays shall be limited to two layers.
Mechanical and electrical continuity of all cable trays and ladders shall be maintained.
Minimum 25 % space shall be provided in each cable tray and ladder rack for future use.
Cable trays / ladders / covers shall be heavy duty, GRP. Stainless steel 316L may be used subject to COMPANY approval. Cable tray/ladder covers shall be provided where cables are likely to be exposed to direct sunlight or mechanical damage. The cover arrangement shall allow free ventilation. Rungs for the cable ladders shall be bolted for GRP ladders and welded for Stainless steel ladders, to the side rails. Thickness of steel used for fabrication of cable tray / ladder / covers shall be 2 mm minimum.
Cable ladder racks if laid in multi-tier shall have sufficient maintenance access throughout the cable length.
All cable ties shall be of stainless-steel insert and PVC coating.
Where specified by ‘process safety discipline’, fire protection coating shall be applied to cable installation to enhance the temperature withstand to 1000°C for one hour.
A minimum spacing of 300 mm shall be maintained between cables and high temperature surfaces.
2.8.3.11
Spacing between cable centres shall be as follows:
i. Between LV power cables and instrument cables: 300 mm
ii. Between HV power cables and instrument cables: 1000 mm
2.9
Cathodic Protection System
2.9.1 Transformer rectifier units shall be provided to step down, isolate, and rectify to supply controlled DC output
to cathodic protection system.
2.9.2 The design requirements of this system will become known only after the completion of soil testing and
completion of the underground piping design.
2.9.3 The DC output rating shall be obtainable with a nominal supply voltage and frequency as specified in Table
#1 for Voltage Utilisation without damage to the transformer, rectifier, or other components.
2.9.4 Rectifier units shall be capable of supplying full load DC output at maximum ambient temperature.
The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party. .
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REVISION: 1
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2.10
Electrical Heat Tracing System
2.10.1 Electrical heat tracing shall be in accordance with IEC 60079-30.
2.10.2 Heat tracing shall be provided for process heating to maintain fluid temperature between required limits.
2.10.3 Separate heat tracing systems shall be powered from normal or emergency power sources as necessary.
2.10.4 Heat tracing circuits shall be energised at 240 V AC, SP&N, 50 Hz via 415 V / 240 V distribution panels.
2.10.5 Heat tracing circuits can be supplied from lighting and small power distribution boards if required.
2.10.6 The following heater types may be used, in order of preference as below:
• Self-regulating/self-limiting heaters • Constant wattage parallel heaters • Skin effect heat tracing for welded pipes.
2.11 UPS System
2.11.1 AC UPS shall be dual redundant or dual independent systems complete with the following for supplying
power to critical services as per Clause 2.2.6.
• 2x100 % battery chargers • 2x100 % inverters • 2x50 % batteries • Static bypass switch • Maintenance bypass and distribution boards • AC UPS of rating above 100 KVA shall be of 3 Phase types.
2.11.2 DC UPS shall be dual redundant or dual independent complete with 2x100 % battery chargers, 2x50 %
batteries, and distribution boards.
2.11.3 Vented NiCad batteries shall be used in all applications for both AC and DC UPS systems.
2.11.4 Each dual redundant or dual independent UPS shall supply power to its own distribution board. The two distribution boards of the dual redundant/independent system shall be interconnected with interlocking to prevent paralleling of the supplies.
2.11.5 Normally, both UPS’s A and B will be operating independently and supplying power to the load connected to distribution boards A and B. Both UPS’s A and B shall be equipped with individual maintenance bypass. A static switch shall be provided to enable uninterrupted and synchronised transfer to bypass and vice versa. For a fault on the UPS the system shall automatically changeover to maintenance bypass. Alternatively, operator can manually initiate the changeover as required.
2.11.6 Each battery bank shall be provided with its own MCCB for isolating the batteries. In addition, the two batteries of a dual independent system shall be interconnected via MCCB such that the batteries can be charged from either battery charger. Two out of three interlocking shall be provided between battery isolating MCCBs and the interconnecting MCCB. The MCCB boxes shall be Ex rated.
The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party. .
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REVISION: 1
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2.12
ECMS System
The Electrical Control and Monitoring System shall consist of the following:
• Control and monitoring of electrical distribution system • Power management • Load shedding • Transformer OLTC control and monitoring • Fault monitoring • Power quality monitoring. • GPS Time stamping • Cyber Security
2.12.1 System Architecture and Configuration
2.12.1.1
2.12.1.2
2.12.1.3
The ECMS control philosophy, system configuration and interfaces with other systems and equipment shall be agreed with the COMPANY.
The ECMS shall be based on a distributed intelligence architecture. The Bay Control Unit (BCU), IED, and protective relays etc. inside the switchgear protection and control cubicles shall be connected to ethernet switch through fibre optic or ethernet cable parallel redundancy protocol (PRP) configuration. It shall be with IEC 61850 communication Protocol for communicating with IEDs.
Typically, the ECMS architecture shall be structured in the following levels: i. Level 1: Local Control-feeder Bay control unit (BCU) or protection IED level or other equipment control. ii. Level 2: Substation Control and monitoring. iii. Level 3: Central Control and monitoring. iv. Level 4: Remote Monitoring.
2.12.1.4
The functionality shall be as close to the feeder level as possible. For example, where possible the fault monitoring, transient disturbance, power monitoring functionalities shall be at bay/feeder level.
2.12.2 Communication
2.12.2.1
The ECMS, with IEC 61850 communication Protocol for communicating with IEDs, shall communicate over an ethernet fibre optic backbone between each substation and control building via a fault tolerant dual ring with protocol (e.g. rapid spanning tree) to re-establish the link following a break in the ring.
2.12.2.2
IEDs shall be networked with data highways within each switchgear line-up.
The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party. .
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REVISION: 1
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2.12.2.3
Systems and devices that do not have Ethernet ports shall be integrated into the ECMS using RS 485 serial links with via data managers or gateways.
2.12.2.4
Communication interfaces with TRANSCO shall follow TRANSCO requirements. [HOLD 5]
2.12.3 ECMS Interfaces
The ECMS shall interface with equipment and systems supplied by others such as below: i. ICSS. ii. Turbine Generators and EDGs (governors, AVRs). iii. Switchgear. iv. ASD driven equipment. v. AC/DC UPS. vi. Capacitor banks. vii. Transformer OLTC
Control of process related loads such as motors and heaters shall be controlled directly from the ICSS. Only the monitoring functions of these feeders shall be communicated to ECMS. Safety critical and control signals from ESD and ICSS to electrical switchgear shall be hard wired through interposing relays.
2.13
Software Tools
2.13.1 System Studies
For the system studies, ETAP software shall be used. PSCAD will be used by SUB CONTRACTOR for Dynamic Studies. PPS/E for grid studies in order to ensure that TRANSCO requirements are adhered.
2.13.2 Lists
Several lists will be prepared during the project such as the consumer list. CONTACTOR’s standard format will be used.
2.13.3 2D Drafting
For 2D drafting, AUTOCAD will be used. For temporary use, other tools might be used such as Excel or Visio.
2.13.4 3D Modelling
For 3D modelling, S3D will be used. 3D design will be used to develop cable routing and accurate lengths. The design will also contain cable ladder/ tray, trench content, and the like that translates into the required material take-offs.
The terms of Contract / Agreement No: CON22-146 shall apply for any disclosure of this document to any third party. .
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Project: Q-32859 - NMDC - Ruwais Folder: RFQ Files