Design Criteria Instrumentation

OFFSHORE DESIGN, ENGG. SERVICES, MR, MUMBAI

DESIGN CRITERIA INSTRUMENTATION

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DESIGN CRITERIA

INSTRUMENTATION

OIL AND NATURAL GAS CORPORATION LTD. MUMBAI

0 REV.

01.10.03 DATE

63 PREPARED BY

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APPROVED &

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CONTENTS SECTION 3.6.1 3.6.2 3.6.3

ITEM SCOPE OF THIS DOCUMENT PURPOSE OF INSTRUMENTATION Standards And Specifications 3.6.3.1 Project Specifications 3.6.3.2 Codes and standards 3.6.4 INSTRUMENTATION SYSTEM PHILOSOPHY 3.6.4.1 Instrument philosophy 3.6.4.2 Instrument power system philosophy 3.6.4.3 Instrument earthing system philosophy 3.6.4.4 Equipment protection philosophy 3.6.4.5 Instrument material selection philosophy 3.6.4.6 Instrument installation philosophy 3.6.4.7 Instrument inspection & testing philosophy 3.6.4.8 Instrument spares philosophy 3.6.4.9 Philosophy for future facilities 3.6.5 BULK ITEM REQUIREMENT FOR INTERFACING 3.6.5.1 Instrument air header 3.6.5.2 Instrument Cables 3.6.5.3 Instrument air tubing & fittings 3.6.5.4 Junction boxes 3.6.5.5 Instrument process connections 3.6.6 GENERAL REQUIREMENTS 3.6.6.1 Tagging and nameplates 3.6.6.2 Documentation 3.6.6.3 Review and approval 3.6.6.4 Vendor pre-qualification 3.6.6.5 Preparation for shipment 3.6.6.6 Receipt and storage Annexure I Instruments & Instrumentation Systems – Well Platform Annexure II Piping Class Annexure III Test And Calibration Form Annexure IV Pneumatic Instrument Branching Connections Annexure V Form B – Deviation List Annexure VI Form C – Commissioning Spares Annexure VII Form D – List Of One Year Spares Annexure VIII Instrument Mounting Details Annexure IX Instrument Label Details

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3.6.1 SCOPE OF THIS DOCUMENT: This document defines the design criteria for the instrumentation and control system envisaged on the new platforms and under the new project. Note: The scope of instrumentation activities pertaining to this project is enlisted in the relevant section of “Scope of Work”. The functional specifications of individual items shall be as per Scope of Work – Instrumentation. 3.6.2 PURPOSE OF INSTRUMENTATION: The purpose of instrumentation is to provide a system such that all the required information / data / signal in the desired form and place are available and they work for safe monitoring, controlling and operation of the process and associated systems and to make the required information available at local control centers and Remote Telemetry Unit (RTU) interface in required form, following the Scope of Work, the Instrumentation Design Criteria and the Functional Specifications of the tender document. 3.6.3 STANDARDS AND SPECIFICATIONS 3.6.3.1

PROJECT SPECIFICATIONS: GS 1050 GS 1060 GS 5006 GS 2005

3.6.3.2

General Specification For Definition Vendor Data Requirement General Specification For Site Condition And Climate General Specification For Protective Coating

CODES AND STANDARDS: Latest editions of the codes enlisted below shall be followed American Gas Association (AGA) AGA Report No. 3

Orifice Metering of Natural Gas

AGA Report No. 8

Compressibility and Supercomressibility for Natural Gas and other Hydrocarbons.

AGA Report No. 9

Measurement of Gas by Multipath Ultrasonic Meters

American National Standards Institute (ANSI) ANSI B 2.1

Pipe Threads

ANSI B 16.5

Steel Pipe Flanges, Flanged Valves and Fittings

B 16.10

Face to Face and End to End Dimensions of Ferrous Valves

B 16.34

Hydrostatic body and leak testing of isolation valves.



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B 16.37

Hydrostatic Testing of Control Valves

B 16.104

Control Valve Leakage

FCI 70.2

Leak Testing of Control Valves

ANSI C 96.1

Temperature Measurement Thermocouples

ANSI B 1.20.1

Pipe Threads, General Purpose

MC 96.1

Temperature Measurement Thermocouples

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American Petroleum Institute (API) API 6D

Specification for pipeline valves

API 6FA

Fire Test for Valves

API RP 14C

RP for Analysis, Design, Installation and Testing of Basic Surface Systems on Offshore Production Platforms.

API RP 14F

RP for Design and Installation of Electrical Systems for Offshore Production Platforms

API RP 14G

RP for Fire Prevention and Control on Open Type Offshore Production Platforms

API RP 500

Classification of Locations for Electrical Installations at Petroleum Facilities Classified as Class 1, Division 1 and Division 2

API RP 520

Sizing, Selection and Installation of Pressure Relieving Devices in Refineries, Part I and Part II

API RP 521

Guide for Pressure Relief and Depressing Systems

API RP 526

Flanged Steel Safety Relief Valves

API RP 527

Commercial Seat Tightness of Safety Relief valves with Metal to Metal Seats

API RP 550

Manual on Installation of Refinery Instruments and Control Systems (out of print)

API RP 551

Process Measurement Instrumentation

API RP 552

Transmission Systems

API RP 554

Process Instruments and Control

API RP 555

Process Analyzers

API 598

Valve Inspection and Testing



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API Standard 2000 Venting Atmospheric and Low Pressure Storage Tanks: Non-refrigerated and Refrigerated. API 1101

Measurement of Petroleum Liquid Hydrocarbons by Positive Displacement Meter

API RP 2001

Fire Protection in Refineries

API 2534

Measurement of Liquid Hydrocarbons by Turbine Meter Systems API Manual of Petroleum Measurement Standards – Measurement of Crude Oil by Coriolis Meter

American society of Mechanical Engineers (ASME) ASME PTC 19.3

Performance Test Code Temperature Measurement

American Society for Testing and Materials (ASTM) ASTM A269

Stainless Steel Tube

ASTM A276.316L

Stainless Steel Fittings

ASTM 370

Standard Test methods and definitions for Mechanical Testing of steel products General Requirements for Carbon, Ferritic Alloy, and Austenitic Alloy Steel Tubes

ASTM 450 British Standards BS 1904

Specification for industrial platinum resistance thermometer sensors

BS 4937

International Thermocouple Reference Tables

BS 5501

Electrical Apparatus for Potentially Explosive Atmospheres

BS EN 60529

Specification for degrees of protection provided by enclosures (IP) codes

International Electrotechnical Commission (IEC) IEC STD 801

Part 3 – EMI and RFI Immunity

IEC 60092-373

Shipboard flexible coaxial cables

IEC 60092-359

Specification for insulation and sheath of electric cables

IEC 60227

Polyvinyl chloride insulated cables of rated voltages up to and including 440/750 V


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IEC 60331

Fire resisting characteristics of electric cables

IEC 60332-1

Tests on electric cables under fire conditions Part I: Tests on single vertical insulated wire or cable Tests on electric cables under fire conditions Part II: Tests on single small vertical insulated copper wire or cable

IEC 60332-3 IEC 61508-1-7

Functional safety on electrical / electronic / programmable electronic safety-related systems

IEC 61000-4-2

Electromagnetic Compatibility (EMC) – Part 4: Testing and Measurement Techniques – Section 2: Electrostatic Discharge Immunity Test

IEC 61000-4-3

Electromagnetic Compatibility (EMC) – Part 4: Testing and Measurement Techniques – Section 3: Radiated, RadioFrequency, Electromagnetic Field Immunity Test

IEC 61131-3

1993 Programmable Controllers – Part 3: Programming languages

Institute of Electrical and Electronic Engineers (IEEE) IEEE STD.472

Surge Withstand Capabilities

IEEE C37.90.1 IEEE 730

Standard Surge Withstand Capability (SWC) Tests for Protective Relays and Relay Systems Standard for Software Quality Assurance Plans Revision of IEEE Std 730-84 and Redesignation of IEEE 730.1-89; IEEE Computer Society Document

IEEE 828

Standard for Software Configuration of Management Plans

IEEE 1042

Guide to Software Configuration management IEEE Computer Society Document

Instrumentation Systems and Automation Society (ISA) ISA 5.1

Instrumentation Symbols and Identification

S 7.0.01

Quality Standard for Instrument Air

ISA/ANSI-S 84.01 Application of Safety Instrumented Systems for the Process Industry ISA 912.13

Part I: Performance Requirements, Combustible Gas Detectors Part II: Installation, Operation and Maintenance of Combustible Gas Detectors


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ISA S 71.01

Environmental Conditions for Process Measurement and Control Systems: Temperature and Humidity

ISA S 71.04

Environmental Conditions for Process Measurement and Control Systems: Airborne contaminants Flow equations for sizing control valves

ISA S 75.01.01 S 75.03

Face to Face Dimensions for Flanged Globe Style Control valves

International Organization for Standardization (ISO) ISO 5167

Measurement of Fluid Flow by means of Orifice Plates

National Association of Corrosion Engineers (NACE) NACE MR 0175

Sulfide Stress Cracking resistant metallic materials for oilfield equipment

National Electrical Manufacturers Association (NEMA) NEMA 250

Enclosures for electrical Equipment (1000 Volts maximum)

National Electric Code (NEC) National Fire Protection Association (NFPA) NFPA 70

National Electrical Code

NFPA 1

Fire Protection Code

NFPA 72 E

Automatic Fire Detectors

NFPA 496

Standard for Purged and Pressurized Enclosures for Electrical Equipment

Other Bodies Report EE170E.98 ER & E Version 1.0, Alarm Management Guidelines Engineering Equipment Materials Users Association (EEMUA) publication No. 191, Alarm Systems – a Guide to Design Management and Procurement All goods and services supplied shall meet all applicable local and international regulations on health, safety and environmental issues.


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3.6.4 INSTRUMENTATION SYSTEM PHILOSOPHY: 3.6.4.1

INSTRUMENT PHILOSOPHY:

3.6.4.1.1

All the offered instruments / equipment or equipment of similar design manufactured by the same supplier shall have been: a) Type tested by the authority approved by the Company. b) In continuous satisfactory service on offshore for a minimum period of two years.

3.6.4.1.2

Field Instruments: All field instruments connected with well monitoring and control, and all facilities that are not to be operated from a central control room, shall be pneumatic except those that are connected to RTU, which shall be electronic, SMART type. All instruments connected to control room and remote unit control panels of related systems shall be electronic, SMART type. (The instruments that are to be connected to the Central Control Room or otherwise shall be governed by the Scope of Work.) For remote control application, remote telemetry, telecontrol and data gathering, electronic instruments shall be used. All final actuation / control device, controlled from remote / Central Control Room (CCR) shall in general be pneumatically actuated. Instrument ranges shall be selected such that the normal operating point is between 35% and 75% of the instrument total range. Hand-held Intrinsically Safe calibration / configuration units shall be supplied to enable online diagnostics, configuration or calibration of electronic instruments from any point in the loop. The number of such calibration / configuration units shall be as per the Scope of Work.

OFFSHORE DESIGN, ENGG. SERVICES, MR, MUMBAI 3.6.4.1.2.1 Pneumatic


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Field Instruments:

The instrument air supply shall conform to ISA S7.3 “Quality Standard For Instrument Air”. Each pneumatic instrument supply shall be provided with independent filter regulator. For pneumatic instruments, dry instrument gas / air supply shall be as follows: 5.5 Kg/cm2 (min.) 7.5 Kg/cm2 (nor.) 10.5 Kg/cm2 (max.) All related equipment shall be suitable for operating in the above-specified range. For pneumatic analog control applications, the actuating signal range shall be 0.2 to 1 Kg/cm2g. For pneumatic on-off applications, the actuating signal shall be 0 or 6.5 Kg/cm2g. 3.6.4.1.2.2 Electronic

Field Instruments:

All electronic transmitters shall be 24 V DC loop-powered type with 4 –20 mA Smart analog output signal. Electronic Transmitters shall have integral LCD display. Where this is not possible, a suitable separate local loop indicator shall be provided. Local electrical control and alarm switches shall be hermetically sealed DPDT Micro Switch activated. The switches shall be rated for 110 V AC – 10 Amps. or 24 V DC – 2 Amps. 3.6.4.1.3

Control Room Instrumentation: All signals to and from the Central Control Room shall be electric / electronic. The standard signal shall be analogue 4-20 mA using 2-wire system, standard thermocouple, RTD output, and / or suitable pulse signal. Instruments located on control panels and central control room (CCR) shall be microprocessor based. On platforms with processing facilities, a Distributed Control System (DCS) shall be provided for monitoring and controlling the process, and for generating alarms in case of process upsets.

OFFSHORE DESIGN, ENGG. SERVICES, MR, MUMBAI 3.6.4.1.4


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Safety Instrumentation System: The new platforms shall be provided with the following safety systems: a) Emergency Shut Down (ESD) System: The ESD system shall initiate process shutdown in case of abnormal condition of the specified process parameter. b) Fire & Gas System: The F&G system shall initiate Fire Shut Down (FSD) upon detection of appropriate level of hydrocarbon and/or H2S accumulation or fire. c) Manual ESD & FSD Stations: The ESD & FSD stations shall be provided at all strategic locations on the platform for manual initiation of ESD and FSD. All shutdown and alarm switches shall be “Fail Safe” and the targeted abnormal conditions shall cause a loss of actuating signal to the final control element. Parameters used for shutdown shall be sensed by independent / individual sensors at independent tapping points. Such sensors and tapping points shall not be shared by any other loop.



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3.6.4.2

INSTRUMENT POWER SYSTEM PHILOSOPHY:

3.6.4.2.1

Pneumatic Supply: For pneumatic instruments, dry instrument gas / air supply shall be as follows: 5.5 Kg/cm2 (min.) 7.5 Kg/cm2 (nor.) 10.5 Kg/cm2 (max.)

3.6.4.2.2

Electric Power Supply: Components of power supply system shall be of highest available quality for reliability and long service life. Power supplies for all transmitters, controllers, signal converters, electric system and components in shutdown system shall be supplied from uninterruptible power supplies. Power distribution to each consumer shall be through proper, independent switch and fuse. Protective fuses shall be of indicating cartridge type mounted in fuse holders. In general, the following Power Supplies shall be used for instrumentation and Control: i. For Process Platforms: 110V AC + 5%, 50HZ + 1% (UPS) for all instruments control. However, all components / instruments / system shall be suitable for 110 V + 10% AC, 50 Hz + 3% ii. For Process & Well Platforms: 24V DC + 5% Battery Negative earthed for Platform interlock system, solenoid valves, Fire and Gas system and status lamp. For details of electric supply system, refer Scope of Work and Design Criteria of Electrical.

3.6.4.3

INSTRUMENT EARTHING SYSTEM PHILOSOPHY: Three separate earthing systems shall be provided: • Electrical Safety Earth – Bonded to the site structure and utilized for electrical safety of metal enclosures and chassis on all instruments and electrical components. • Instrument Clean Earth – Insulated from the site structure and other metal work, utilized for instrument cable screens and bonded to the main electrical earthing system at a single point. • Intrinsically Safe Earth – Insulated from the site structure and other metal work, utilized for termination of IS zener barrier earth connections, and bonded to the main electrical earthing system at a single point.



3.6.4.4

EQUIPMENT PROTECTION PHILOSOPHY:

3.6.4.4.1

Environmental Protection:

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All instruments / equipment and installation material shall be suitable for the overall climatic conditions (specified in GS 5006), the position within the installation and the local environment, with particular attention to site ambient conditions. The conditions will include exposure to Hydrocarbons, H2S (in case the process fluid is sour), moist salt laden atmosphere, sea spray, sunlight, monsoon rainfall, temperature, humidity, wind, fungal growth, vibration and shock, EMI and RFI. All equipment shall also be able to withstand these conditions during shipment, storage and installation prior to commissioning. Instrumentation shall withstand not only the quoted environmental conditions, but also the periodic testing of the Deluge or Fire Hose System. As all of the Company’s sites are subject to seismic activity as indicated in the General Scope of Work and General Design Criteria, all instrument / electrical frames, panel and racks shall be fixed in position suitably secured. In view of the highly corrosive ambient conditions, all internal and external parts which are not inherently corrosion resistant by choice of material shall be prepared and finished by plating or paint finish in accordance with the General Specification for protective coating (GS 2005). Seals and purges shall be used as necessary, to ensure reliable instrument performance. All field instruments shall be provided with necessary weathering and anticorrosion protection. All field instruments shall be provided with plastic bags (min. 5 mm thick) to protect them during handling, installation and commissioning. The bags shall be kept in place at all times except during work on the devices. Drying agent (desiccant) with humidity indicator shall be put inside the bag and it shall be replaced when color of the indicator changes from blue to pink Additional protection by other means such as canvas or leather blankets shall be provided to prevent damage caused by welding during construction work at nearby location. Labels and tags that may be exposed to paint spray, shall be temporarily masked with a transparent material during construction activities, which shall be removed at the time of hand over of the work. Plastic plugs shall be fitted to all instrument tubing and air, process and cable entry ports until final connections are made. 3.6.4.4.2

Ingress Protection: All field instruments shall have ingress protection to NEMA 4X or IP 66. All instruments installed inside pressurized equipment / control rooms shall have ingress protection to IP 42 as a minimum.



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Tropicalization: All electrical components shall be tropicalized to protect against humidity, moisture and fungal growth by means of hermetically sealed units, protective coating on circuit boards, gold plated edge connectors, etc.

3.6.4.4.4

Hermetic Sealing: All relays and switches shall be hermetically sealed, and those utilized in 24 V DC control logic circuits shall have gold plated contacts rated 0.5 Amp at 24 V DC. Those interfacing with field equipment shall be rated 2 Amp 24 V DC. All switch contacts shall be SPDT minimum.

3.6.4.4.5

Hazardous Area Instrumentation: The Contractor shall classify hazardous areas in accordance with API 500 and specify various equipments accordingly. All instruments which are mounted outside of normally pressurized control / equipment rooms shall be certified by bodies such as FM / UL / BASEEFA / CSA / DGMS for use in Class I, Division I, Group D, T3 hazardous area, even if the instrument’s location is classified as a normally non-hazardous area. Intrinsic safety approval shall be based on entity concept and necessary compatibility checks shall be carried out by Contractor before selecting any equipment. Intrinsically safe protection using external barriers shall be provided for all process transmitter loops (closed as well as open). Isolating barriers shall be of the plug-in type, mounted on modular back plane termination units. Each input and output in a loop shall have a separate barrier. No barrier shall be shared between two loops in input / output. All other instrument loops shall be provided with explosion proof / flame proof protection. Solenoid valves, electric hand switches, signaling lamps and Intercom / Paging system shall be Explosion proof / flame proof to Ex d or NEMA 7. If specialist instrumentation cannot be provided with the above methods of protection, then alternative methods suitable for the classified area and certified by an acceptable Authority may be proposed. The Contractor shall submit a technical report justifying the instrument selection for the Company’s consideration.

3.6.4.4.6

R F Interference: All equipment shall remain unaffected by radio transmissions (Levels of permissible RFI shall be as per IEC 801). Band-pass and / or band stop filers shall be fitted, as necessary.



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Sealing: Seal systems shall be used to isolate instrument from the process fluid encountered in the following services: a) b) c) d) e)

Wet gas, which may condense in the instrument lines. Process fluids that vaporize, condense or solidify under operating pressure and ambient temperature. Process fluids that will subject the element to high temperature. Corrosive process conditions. Viscous liquids.

Sealing may be accomplished with diaphragm seals. All venting instrument and pilot valves shall have bug screens fitted to atmospheric vents. Additional protection requirements of individual instruments, if any, shall be as per the relevant functional specification.

OFFSHORE DESIGN, ENGG. SERVICES, MR, MUMBAI 3.6.4.5


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INSTRUMENT MATERIAL SELECTION PHILOSOPHY: All materials and equipment furnished shall be new and unused, of current manufacture and the highest grade and quality available for the required service, and free of defects. Materials shall be selected with regard to the following criteria: •

Suitability for the specified process conditions, with SS 316 as the minimum for use outside pressurized rooms, except for salt-water service, in which case, it shall be Monel.

•

Suitability for the corrosive effects of the atmosphere.

•

Galvanic compatibility between dissimilar materials, with isolating bushes, plates, used where necessary to prevent corrosion due to galvanic action.

•

The possibility of selective corrosion in certain alloys and stress corrosion cracking in certain high strength materials when used in corrosive environments. Where H2S may be present in process streams, the Contractor shall ensure that all wetted metallic parts of instruments, valves, tubing and fittings etc., which may come in contact with the process fluid, shall comply with the requirements of NACE MR 0175, latest editon.

•

Company approval shall be obtained for the use of aluminium for any instrument component. Aluminium may only be used if no other suitable material is available but shall not be used for any component in contact with the process fluid. If aluminium is used for any housing or other component, it shall be suitably coated and certified as copper free i.e. less than 0.4% copper by mass.

•

Material for all junction boxes, and instrument electronics and termination housings shall be SS 316.

•

All proposed vendor standard plastic components if any shall be non-toxic and fire resistant, UV stabilized and compatible with the environmental conditions.

•

All spindles, bushings, bolting, screws etc., shall be manufactured from a suitable grade of stainless steel as a minimum. All bolts and screws shall have a flat 316 SS washer under the nut, and the thread length shall be such that there is complete full engagement of the nut, with a minimum of two threads protruding.


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•

All fittings, supports, panels, fasteners, brackets, grider clamps, angle, tube clips, saddles, channel, U-strut type channel, cable ladder, conduit, cable glands and the like shall be made of SS 316.

•

All material for instrumentation, in contact with process fluid containing CO2 in excess of 2 Kg/cm2 psi partial pressure, shall be as follows: Fluid Temperature

< 71 oC > 71 oC

•

Material to be used

ASTM A182-F316 (316SS) ASTM A182-F51 (2205 duplex steel)

Moulded polyester parts shall be anti-static for hazardous area locations, and in general be constructed from UV-stabilized glass reinforced polyester. Surface resistance shall not be less than 109 Ohms. Impact resistance to be -25% (EN 50.14)

The material selection criteria of individual instruments shall be as per the material selection chart given in the relevant Functional Specification. The details of various piping classes mentioned in these material selection charts shall be as per Annexure II of this document.



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INSTRUMENT INSTALLATION PHILOSOPHY: All work shall be of the highest quality craftsmanship and shall conform to the best applicable engineering practices, and, relevant codes referred in the bid document. All instruments shall be installed in a neat workmanlike manner ensuring ease of operation and maintenance. The Contractor shall prepare hook-up and installation detail drawings regarding each type of instrument for the Company’s approval, and shall carry out the installation in accordance with these approved drawings. The Contractor shall install instruments and equipment with due consideration of the following: • •

• • • • • • •

• •

No instrument with the exception of pressure gauges and temperature indicators, shall be installed in such a way that it depends on its impulse piping or electrical connections for its support. Positioning of equipment shall not constitute a safety hazard. Where possible, instruments shall be mounted so that they are protected from the effects of rain and sun, while maintaining the requirements for access and visibility. Where this is not possible, the Contractor shall provide a fixed cover or hood to protect instruments, without impairing access or visibility Visibility and accessibility for both maintenance and operations purpose. Ease of access for lifting heavy items of equipment such as valves. All instruments and valves shall be free from vibration. Instruments shall be mounted / connected so as not to stress vessel nozzles or pipe tapping. All local process-connected instruments shall be located as close as possible to the point of measurement while still being accessible from the deck, ladder or a platform. Instruments requiring frequent routine access (including hand-valves, manual resets, manual switches, etc) shall be mounted approximately 1.4m above the deck or platform for ease of accessibility. Instruments shall be properly supported on brackets or mounted on subplates, or placed on a suitable pedestal, pipe stand or structural support. Pipe or structural stands may be welded directly onto platform plate, with a suitable penetration in the grating, where applicable. Instruments, tubing, cables and cable ladder shall not be fixed to gratings or handrails. Instruments (other than pressure instruments) shall not be mounted directly on process piping without the Company’s written approval.


• •


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Instruments or instrument lines shall not be supported on handrails unless approved by the Company. Fittings such as instrument isolating valves and instrument air or gas regulators shall be supported either on the instrument stand or closecoupled to the instrument in a manner that no undue stress is imposed o the tubing or instrument.

Instrument stands or panels shall be in accordance with the approved drawings, with consideration for: • • • •

The most direct routes for tubing and piping to and from the stand, using common tubing runs and avoiding crossovers. Ease of inter-connections between instruments. Ease of access for on-site calibration and / or removal of instruments. Minimum interference between tubing, piping and cabling to instruments.

A 316 SS filter regulator with gauge shall be provided for each instrument requiring regulated gas or air supply. All open ports (vents / drains) on field instruments shall be made to face downwards if it is already not so and fitted with bug screens. The general instrument mounting details shall be as per Annexure – VIII of this document. Additional installation requirements of individual instruments, if any, shall be as per the relevant Functional Specification.



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3.6.4.7

INSTRUMENT INSPECTION & TESTING PHILOSOPHY:

3.6.4.7.1

General:

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The Contractor’s quality plan shall include a comprehensive fully documented inspection and testing plan specific to the project. The procedures shall include inspection specifically for compliance with hazardous areas requirements, including current certificate, without which no circuit or loop shall be energized. All testing, calibration and pre-commissioning shall be done by the Contractor. The Contractor shall also provide assistance as required during commissioning activities. The Contractor shall provide suitable workshop facilities and shall provide all necessary test and calibration instruments and equipment. The Company reserves the right to reject any or all test and calibration work if found not complying with the Specification requirement. The Contractor shall complete and submit documentation for all calibration, testing and precommissioning. Company Representative prior to shipment shall check out panels, consoles, and packaged instrument assemblies for their compliance with specification requirements. The Contractor shall in the presence of the Company Representative, verify by inspection, calibration and loop testing, that, all instrumentation in field and control room including local and remote/central control panels, are complete and operable as per specification requirement. All testing and calibration shall be subject to approval of the Company. In addition to calibration/testing, loop checking, setting for safety devices like process switches, safety valves etc. and simulation testing of all interlock and shutdown systems, done at fabrication yards, the same shall also be carried out at offshore site as well. In general, the pipes and tubes shall be cleaned before testing. They shall then be subject to hydrotest (or other applicable tests) and then blow dried. 3.6.4.7.2

Flushing of Lines: The Contractor shall remove in line instruments like flow meter, control valves/safety valves, if necessary, and provide spool pieces/flanges prior to flushing of lines.



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Instrument Supply Lines: Instrument air/gas piping and tubing shall be disconnected upstream of all filter/regulators before testing, the piping and tubing shall then be hydrotested as explained below and then shall be blown down to remove hydrotest water, slag and mill scale from lines. Instrument air supply lines shall be blown with instrument air prior to connecting to instruments. Instrument air/gas mains shall be isolated from the instrument and pressurized to 11/2 times maximum working pressure with instrument air, they shall be isolated from the pressure source and the pressure reading on a test gauge shall not fall by more than one psig in ten minutes.

3.6.4.7.4

Instrument Signal Lines: Instrument signal lines shall be blown with instrument air prior to connecting to instruments. All air/gas tubing shall be tested and inspected by one of the methods given in Instrument System & Automation Society (formerly known as Instrument Society of America) Recommended Practice RP 7.1 “Pneumatic control circuit pressure test”. Clean, oil free instrument air shall b e used for the test.

3.6.4.7.5

Impulse Lines: All process impulse lines shall be disconnected and flushed with potable water. Air lines shall be blown down with filtered air. Hydraulic lines shall be flushed with hydraulic oil. After flushing process impulse lines shall be isolated from the instrument and pressurized hydraulically to 11/2 times maximum working pressure corrected for ambient temperature. They shall then be isolated from the pressure source and the pressure reading on a test gauge shall not fall at a rate exceeding one psig/hour.

3.6.4.7.6

Direct Mounted Instruments: For direct mounted instrument such as level gauges, level transmitters (displacer type), level switches etc, the installations shall be pressurized to maximum operating pressure slowly and steadily with the instruments. The installations shall then be isolated from main pressure source. The pressure shall not fall at a rate exceeding one psig/hr.

3.6.4.7.7

Wiring: Wiring shall be checked to ensure that it is correctly connected and properly grounded. Insulation test shall be carried out on all wiring taking necessary precautions. Correct connections of all electric or pneumatic switches shall be checked.



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3.6.4.7.8

Calibration & Testing:

3.6.4.7.8.1

The Contractor’s instrument personnel shall calibrate instruments. This calibration shall when possible, be done with the instrument or system in place, otherwise calibration prior to installation or removal for calibration shall be done. The Contractor shall provide written results of all instrument calibration in prescribed format and shall submit such formats well in advance for Company’s approval. The status/progress of testing calibration for each loop shall be reported to the Company in the format provided in Annexure II of Instrumentation Design Criteria. The Contractor shall submit document confirming that the testing equipment to be used for calibration purpose are certified and calibrated. Submission of this document shall be done at least 6 (six) months prior to calibration of the relevant instrument.

3.6.4.7.8.2

In general, all tests shall simulate, as closely as possible, design process conditions by use of manometers, potentiometers, deadweight testers, test pressure gauges, etc. utilizing hydraulic and pneumatic suppliers. Three (3) point calibration shall refer to the input signal to an instrument equivalent to 0, 25, 50, 75 and 100 per cent of the instrument range upscale (rising) and 75, 50, 25 and 0 percent of the instrument range downscale (falling). All instruments, unless otherwise noted, shall be calibrated in both upscale and downscale directions and, if necessary, adjusted until their accuracies conform to those limits stated by the manufacturer. Upon completion of these tests, the instruments shall be drained, the components removed and the shipping stops replaced.

3.6.4.7.9

Testing And Calibration Report: The Contractor shall provide written results of all above tests and if required by the Company, provide reasonable evidence of the satisfactory condition of test equipment. All errors of faulty workmanship discovered during this testing shall be corrected to the satisfaction of the Company The installation and testing requirements of individual instruments / systems shall be as per the relevant Functional Specification.



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3.6.4.8

INSTRUMENT SPARES PHILOSOPHY:

3.6.4.8.1

For all major equipment, the Contractor shall include normal commissioning spares as a part of the equipment. The Contractor shall also furnish separately, list of recommended spares for two year’s trouble free operation along with the prices for purchaser’s review.

3.6.4.8.2

All spare parts shall comply with the same standards and specifications as the original equipment and shall be fully interchangeable with original parts.

3.6.4.8.3

All spare parts shall be marked with the manufacturer’s part number, name and / or reference number.

3.6.4.8.4

All spare parts shall be packed separately from the main instrument, and shall be properly protected to prevent deterioration and damage during shipment and storage. The spares requirement of individual systems shall be as per the relevant functional specification.



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PHILOSOPHY FOR FUTURE FACILITIES: Provision shall be made in all control systems such as control room instrumentation, pneumatic shutdown panels and local panels etc to operate and control future facilities as shown in P&ID and / or indicated in the Scope of Work. All panel / cabinet mounted instruments and accessories required for this purpose shall be supplied and installed by Contractor.



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3.6.5 BULK ITEM REQUIREMENTS FOR INTERFACING: 3.6.5.1

INSTRUMENT AIR HEADERS Instrument air/gas mains shall be in accordance with the piping specification of appropriate service and operation rating. The size of instrument air/gas mains shall be established in accordance with the table below unless otherwise specified. Nom. Pipe Size

Max. Members of Users

½”

3

¾”

14

1”

23

1½”

50

2”

100

All take-off for branch lines shall be of SS 316 & shall be from the top of the main header with SS 316 block valves equal in size to the branch line. All low points shall have a ½” valve installed as a drain and blow down point. The branches to individual pneumatic instruments shall be as per the Hook-up drawing provided in Annexure III of this document. Every pneumatic instrument requiring instrument air / gas supply, shall be provided with a small volume 316 SS filter regulator fitted with integral relief valve and output gauge to ensure that suitable quality and pressure air is received by the instrument. Wherever the air / gas sub header ends in a distribution manifold, each manifold take-off shall supply only one user and shall be labeled with the user’s tag number. Four spare outlets fitted with plugged valves shall be provided on each distribution manifold for future use. Manufacturer or fabricator supplying equipment or vessels mounted on skids, which incorporate instrumentation requiring pneumatic supply, shall install a pneumatic supply header, of proper size, on the skid with end connection at skid battery limit. All pneumatic instruments on the skid, shall be fed with pneumatic supply form this header. The non-skid supply piping shall terminate at skid boundary and the location and size of the supply connection shall be noted on vendor approval drawings.



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INSTRUMENT CABLES: (The general requirements of cables are as given below. Also refer relevant Electrical Specification for further details on cables.)

3.6.5.2.1

Cable Types: The inner and outer jacket of the cables shall be made of extruded flame retardant 90oC PVC to IS 5831 type ST2. The O2 index of PVC shall be over 30. The temperature index shall be over 250 oC. The cables used shall in general be of the following types: a) Fire Resistant Cables: Cables of this type shall be used for all circuits that have a safety-related function, or are required to remain operational under emergency conditions. This includes all parts of F & G Systems, ESD systems, PA Systems, warning beacons and platform status lamps, fire control systems, and power supplies to those systems. These cables shall comply with the requirements of IEC 60331 and IEC 60332-3 (Category C) or better. b) Fire Retardant Cables: Cables that are not Fire Resistant shall be Fire Retardant type and shall comply with the requirements of IEC 60332-3 (Category – C). The properties of fire retardant cables to be used for different applications shall in general be as follows: i) Signal Cables: Twisted single pair/triad cables shall be 600 V rated and shall have 1.5 sq. mm. PVC covered, 7 stranded Copper conductor, 100% aluminium Mylar shielding shall be provided with 25% overlap on either side & 18 AWG 7 strands copper drain conductor. These shall have PVC inner jacket, galvanized steel armoring and overall PVC outer jacket. Ripcord shall also be provided. Multipair cables shall have following additional features: • Pair identification by colour coding/numbering. • Individual pair shielding apart from overall shielding. • One pair of 22 AWG 7 strand copper wire with PVC insulation, for communication. • Maximum of 12 pairs per cable ii) Control / Alarm / Status Cables: These shall be same as signal cables except there shall be no individual pair shielding in case of multipair cables.



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iii) Compensating Cables for Thermocouples: These cables shall be generally same as signal cables except conductor shall be solid 16 AWG in single pair and solid 20 AWG in case of multipair cables. Colour coding, thermoelectric characteristics and limits of errors shall be as per ANSI MC 96.1. iv) Power Cables: Power cables shall be 3-core, minimum 2.5 mm2 copper conductors with PVC insulation, galvanized steel armoring and overall PVC sheathing. c) Special Cables: Cables for special instruments like analyzer, turbine meter etc. shall be as per manufacturer’s recommendation. 3.6.5.2.2

Cable Sizes: Cables with individually screened pairs shall be used for very low-level signals such as thermocouple wiring or similar, or for pulsed signals. Types and sizes shall be as follows: • • •

Analogue multipair cables: Overall screen 1.5 mm2 conductors Digital multipair cables: Overall screen 1.5 mm2 conductors Digital cored cables: For 24 VDC power, no screen, 2.5 mm2 conductors

Larger sizes shall be used where required to keep cable voltage drop below 2% of the supply voltage. 3.6.5.2.3

Cable Shielding: All instrument signal cables shall be continuously shielded with the shield grounded at the same point as the signal circuit, generally at the control instrument (panel) end.

3.6.5.2.4

Cable Runs: All instrumentation cables shall be supported / layed in trays. Power cables shall not be run in trays carrying signal cables. The physical separation of power and signal cables shall be as per API-550 Part –I SECTION VII. Cables in intrinsically safe circuits shall preferably be not run in the tray for cables in non-intrinsically safe circuits. If run in the same tray a metallic earthed separator shall be provided.



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Conduits carrying intrinsically safe cables shall be painted with the blue color bands at each end. Where cables are run through conduit, the entry and exit shall be smooth and free from burrs. The use of conduits shall be kept to a minimum, as far as possible. Cables must be pulled into conduit in a way that ensures there is not damage to the cable. Splices shall be made only at terminals, in instruments or approved equipment/junction boxes in any cable path shall be limited to one only. 3.6.5.2.5

Cable Marking: All cables shall be identified with stainless steel cable markers securely fixed to the cable with cable tie wraps at the following locations: • • •

All cable glands Entering and leaving cable ladders, ducts and supports Both sides of walls or bulkheads

Cable markers shall be fitted during or immediately after cable installation. 3.6.5.2.6

Cable Identification: All wiring, cables, tubes, multi-tube bundles, junction boxes and auxiliary equipment shall be suitably identified as per applicable codes and practices. Plastic adhesive tapes shall not be used for identification. Identification and details of all such equipment and wiring/tubing shall also be clearly marked on appropriate drawings. All wiring shall be tagged with slip on or clip-on wire marker at both ends with the wire number specified on the drawings. Terminals for electrical connections including thermocouple extension wires shall be numbered and identified to indicate polarity, ground Connections, test connections, and any other pertinent information. Cable cores shall be coloured as follows: • 24 V DC Digital Circuits: Positive – White, Negative – Black • Analogue Circuits: Positive – White, Negative – Black Cable outer sheaths shall be coloured as follows: • Intrinsically Safe: Light Blue Black • Non-IS Cables:



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Cable Segregation: The Contractor shall ensure that there is no interference between cables having different voltage or signal types. Instrument cables shall be segregated from antenna cables and others carrying RF signals so as to avoid interference. Very low-level signals, such as thermocouple wiring, or of pulsed signals or any other signal types, which may be liable to affect or be affected by any other cables, shall have individual and overall screens and shall be installed on a separate tray or ladder adequately separated from other cable systems. Intrinsically safe signal cables may be run on the same tray as non-IS signal cables if they are segregated by metal barrier.

3.6.5.2.8

Cable Installation: All instrument signal cables shall be continuously screened, with screens grounded at the equipment room end only, and securely insulated at the field end. All cables exiting equipment rooms shall be armoured, including serial link and data highway cables. For ease of instrument disconnection, an adjustable elbow or union shall be provided between the terminating gland and the instrument. A neat loop of cable 250 mm diameter shall be left immediately adjacent to all instrument devices in the field. Cabling to locally mounted instruments shall not be routed across normal or emergency walkways nor interfere with access to equipment. Cable transits shall be used to provide gas-tight cable penetrations through decks or firewalls.

3.6.5.2.9

Cable Termination: All cables shall be terminated using double compression type glands on explosion proof equipment. These glands shall be explosion proof, certified. All cable glands in outdoor service and on equipment subjected to salt water spray shall be weather proof also. All terminations shall be screw clamp type terminals for 2.5mm2 conductors minimum (no flying leads) and correctly certified where necessary. Insulated crimp lugs shall be used for all cable core connections, with only one conductor per terminal side.



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No wire shall be terminated/left with mechanical strain on it in any conduit or trunking. Cables shall be terminated in 316 SS glands, suitably certified where necessary. The inner sheath shall be left on the cable after the gland, and removed at the point of entry into wiring duct. Cable cores shall not be ‘pig tail’ finish. Cable screens and drain wires shall be securely insulated at the final field termination. The communications conductor of a cable shall be terminated in the bottom terminal(s) of a row of terminals. Printed sleeve-type ferrules shall be fitted to all cable cores on both sides of every core. ‘C’ type and adhesive type shall not be used. All cables shall be individually loomed at maximum fixing centers of 60 mm and where cores leave the loom. Only one conductor shall be used per terminal side. Cable entry to control room/other rooms shall be through listed multicable transits. Terminal blocks shall be non-hygroscopic, Vibration proof, stack on type and shall use captive screws for terminals. Terminals shall be tinned or Silver plated. All terminations shall be through use of wire lugs. Terminal blocks shall be flame retardant type. Cable Termination for Skid Items: Manufacturer or fabricator supplying skid mounted equipment or vessels with instrumentation which provides or utilizes off skid alarms / shutdowns / control functions, shall terminate signals on a central junction box, near skid boundary, available for hook-up by Contractor. The location of this junction box shall be noted on vendor drawings. 3.6.5.2.10Cable

Junction Boxes:

Separate junction boxes shall be used for intrinsically safe wiring. Junction boxes in any cable path from field to control room shall be limited to one only. Instrument junction boxes shall not be used for electrical power cables.



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Field junction boxes shall be certified for use in hazardous area in which they are installed. For intrinsically safe circuits, boxes certified Increased Safety Ex e shall be used. For non-intrinsically safe circuits, boxes certified Explosion-proof / flame-proof Ex d shall be used. All enclosure cable entries shall have NPT threads. Where this is not possible a certified 316 SS adaptor shall be fitted. All Ex e and Ex d enclosures shall have all spare entries sealed with suitably certified 316 SS plugs. Cables shall not enter through the top or sides of outdoor enclosures. For indoor enclosures, bottom entry is preferred. Entries shall be suitably spaced to enable ease of installation of cable glands. Tapped cable entries shall be of good quality, without stripped or damaged threads. The thread shall be continuous and shall permit the cable gland to fit squarely against the gland plate (or enclosure). Where the gland plate is not thick enough for tapping, cable glands shall be fitted with double locknuts. The threads of all cable glands and adaptors shall be greased on assembly. Cable glands fitted to all Ex e enclosures, and industrial enclosures, shall have a nylon or lead sealing washer between the Cable Gland and Gland Plate (or enclosure) to ensure IP 66 protection. Sealing washers shall not be fitted to glands entering Ex d enclosures. All junction boxes shall be effectively sealed, once uncrated or fitted into position. All lids shall be replaced during any break in work. Where this is impractical, e.g. large multi-cable junction boxes, a heavy PVC sheet shall be used to cover the junction box to exclude rain and dust. All terminals (including unused terminals) shall be tightened down. For communing of terminals, feed through cross connection bar shall be used. Comb connectors shall not be used. Requirements of Ex d enclosures: • • •

Minimum degree of protection shall be IP 66 Ex d enclosures shall not be drilled or machined under any circumstances Damaged enclosures shall be completely replaced


• • • •


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Flange surfaces shall be clean and undamaged All fixing bolts shall be present and tightened to the correct torque All glands, adaptors, reducers and plugs shall be certified All metal flanges and box lids shall be sealed after assembly with a greaseimpregnated cloth.

Requirements of Ex e enclosures: • • • • •

Minimum degree of protection shall be IP 66 Damaged enclosures shall be completely replaced The contents of an Ex e enclosure shall not be altered without the prior approval of the Company’s Electrical or Instrument Engineer. Damaged terminals shall be replaced with approved Ex e terminal All glands, adaptors, reducers and plugs shall be certified



3.6.5.3

INSTRUMENT AIR TUBING & FITTINGS:

3.6.5.3.1

Tubing Material & Sizes:

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All tubing and fittings shall be imperial sizes, expressed in nominal outside diameter (OD) and all threads shall be NPT Tubing and fittings shall be of 316 SS to ASTM A269 unless otherwise specified. The minimum size shall be ¼” OD. Tubing runs shall be supported and protected. Tube fittings shall be of double ferrule, pressure seat, no torque type for use on heavy or thin wall tubing, and shall be of reputable makes (such as Swagelok or Parker). Ferrule and nut shall be of the same material as the fittings. Flare type fitting shall not be used. Stainless steel tubing shall be soft annealed seamless type 316 SS as per ASTM A269. Sizes shall be as follows: S. No. 1

Application High-pressure hydraulic lines

Size ¼”O.D. X 0.035” W.T. 3/8” O.D. X 0.035” W.T. & 3/8” O.D. X 0.049” W.T.

2

ESD/FSD loop

3/8” O.D. X 0.035” W.T.

3

Pneumatic supply to shutdown valves

3/8” O.D. X 0.035” W.T. 316 SS tube

4

Process impulse lines

1/2” O.D X 0.065” W.T. 316 SS tube

For instruments on API 5000# class piping, the impulse lines and fittings shall be as per piping specifications. Monel tubing shall be used on sea water and produced water service and shall be fully annealed seamless as per ASTM B-165 with size ½” O.D. X 0.035” W.T. Threaded connections shall be NPT for all components and piping and tubing systems for process and utilities connections. TFE threads sealant shall be used on all threaded connections. Tape shall not be used.



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Tubing shall be supported and protected by stainless steel angle / channel or ladder / tray along the complete length of each run and shall be fastened with stainless steel saddles at a maximum of 1 m intervals on straight runs. Channel or tray support for tubing runs shall be sized for a minimum capacity of 30% greater than that required. All pneumatic exhaust ports and breathers shall be fitted with bug screens, installed facing downwards. Hardness for tubes shall not exceed RB 70 – 79 and hardness for fittings (ferrules) shall be such that, there is a minimum hardness difference of 5 to 10 between tube and fittings for better sealing. 3.6.5.3.2

Tubing Testing Requirements: Testing requirement for tube & tube fittings (Both Hydraulic & Pneumatic): a) The tests shall be according to ASTM A450. b) The tests specified below shall be carried out on samples drawn at random. c) The test fluid for hydraulic testing shall be mineral oil having viscosity grade of ISO VG46 and ISO VG32. d) Tests to be carried out are: c.1)

Proof Pressure Test Test assemblies (tubes and fittings) selected at random shall be subjected to a pressure of 1.5 times the maximum working pressure applied at the rate of 200 kg/cm2 per minute and maintained at the final pressure for five minutes without leak.

c.2)

Dismantling and Re-assembly Test A minimum of three test assemblies that have successfully completed `Proof Pressure Test’ as above shall be disassembled and assembled ten times after which they must pass the Proof Pressure Test’ again.

c.3)

Hydraulic Impulse Cum Vibration Test



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A minimum of three test assemblies that have successfully completed the `Proof Pressure Test’ shall be mounted on a hydraulic impulse cum vibration test bench. They shall be subjected simultaneously to pressure impulse of 1.5 times the maximum working pressure at 30 to 100 cycle per minute and vibration in two mutually perpendicular planes at 1300 to 2820 cycles per minutes for a minimum of 5 X 10 pressure impulses and 20 X 10 vibration cycles. The only retightening is after the first 1000 pressure impulses to allow for bending. During the testing the leakage shall not exceed 1cm3/Hr/Assembly. c.4)

Vacuum Test A minimum of three test assemblies that have successfully completed the ‘Proof Pressure Test’ shall be subjected a negative pressure of 700m Bar and then disconnected from Vacuum Pump. The assembly must maintain the vacuum pressure for fifteen minutes.

3.6.5.3.3

Tubing Installation: The primary instrument block valves for all instruments shall be as per piping specifications. All the drain valves shall be in 316 SS/MONEL. All impulse lines shall be run with a slope not less than 1 in 12 except where otherwise specified. Direction of slope is to be downward from the process for liquid service and upward from the process for gas service. Tubing shall be joined by compression fittings. Instrument lines shall be run in the vertical plane as far as possible and shall be run with the minimum number of changes of directions consistent with good practice and neat appearance. All pipe and tubing shall be run in horizontal and vertical planes only. Tubing shall be bent with correct size tubing bender where required to avoid the use of fittings. Tubing cutter shall always be used to cut tubing. The use of short lengths of tubing in long runs shall be avoided, to avoid the use of fittings. All tubing shall be run in such a manner as to give the maximum protection against mechanical damage. Tubing runs shall be grouped together and clamped where possible. Tubing shall be arranged so that couplings can be tightened without distorting lines. Instrument tubing shall not run on trays intended for cables and shall not share the same transit with cables.


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Tubing run in permanent enclosures shall not have joints, except at special junction boxes provided for this purpose. Where tubing is run in permanent enclosures, the Contractor shall ensure that entry and exit of such enclosures is clean and smooth. Pipes or tubes installed but not connected, shall have the ends closed in approved fashion to prevent the entry of foreign material by suitable caps or plugs. All reasonable precautions shall be taken to prevent foreign material entering tubing / pipelines before and during erection. No pipe or tube shall be left with mechanical strain on it. Where the length of transmission tubing exceeds 60 Mtrs. (200 Ft.) the Company should be consulted as to the necessary of installing signal booster relays. Where permanent enclosures are left with space for instrument tubing to be pulled in at some future date, a galvanized pull wire of adequate size shall be left in the tray. On tubing to pipe connections and in making of screwed pipe joints, Teflon tape shall be applied to make thread in a manner to insure tape is not over the end of the male fittings. 3.6.5.3.4

Piping Supports: Piping and tubing shall be adequately supported and fixed at distances not exceeding those in the following table: Single Tubing 3

/8” O.D. and less

Max. Distance Between Supports Continuous

½” to ¾” Nom. Size

2 Mtrs. (6 ft.)

¾” to 1” Nom. Size

3 Mtrs. (9ft.)

Multi tube Bundles

3 Mrrs. (9ft.)

All field-mounted instrument air tubing shall be supported with galvanized steel angles or channels of minimum 1/8” thickness fabricated to present a neat appearance.



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All instrument tubing supports shall be galvanized prior to installation. All mechanical ferrule seater shall be used on tubing for 140 kg/cm2 (2000 psi) and over. Pipe bushing shall not be used. Plugs shall be of bar-stock with hex heads. Signal transmission shall be through ¼” O.D. X 0.035” W.T. tubing run singly or in bundles. If extended lengths of multiple tubing are to be run, multiple bundles and junction boxes with weatherproof entries may be used to the best advantage. Manufacturer or fabricator supplying skid mounted equipments or vessels with instrumentation, which provides, or utilizes pneumatic, offside alarms, shutdowns, or control functions shall tube signals to a central bulkhead, near skid boundary, available for hook up by the Contractor for connection to offside equipment. Location of the bulkhead shall be noted on vendor drawings. Differential or static pressure sensing lines shall not exceed 6 Mtrs. (20 Feet) for direct connected or locally mounted instruments.



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JUNCTION BOXES: Instrument junction boxes shall be certified for use in the hazardous area in which they are installed. For intrinsically safe circuits, boxes certified Increased Safety Ex e shall be used. For non-intrinsically safe circuits, boxes certified Explosion Proof / Flame proof Ex d shall be used. Boxes shall provide IP 66 ingress protection. The construction of junction boxes shall be as under: a) Increased Safety Junction box construction shall be 1.5 mm 316L SS. Boxes shall be bottom entry with a removable 316 SS gland plate. The gland plate shall be drilled and tapped, 6 mm thick for tapered threads and 3 mm thick for parallel threads. The plate shall be bolted to the box with 316 SS bolts, sealed with a neoprene gasket and fitted with an 8 mm earthing stud. All incoming cables shall enter from the sides of the junction box. Outgoing cable shall be from the bottom of the junction box. Boxes shall have four external mounting lugs, two top and bottom, drilled with 10 mm fixing holes. A full size removable stainless steel gear plate shall be fitted inside each box. Terminals shall be Ex e rail-mounted tunnel-type made of melamine. Wiring ducts shall be coloured blue. Boxes shall have doors hinged minimum at two points with a neoprene seal fitted all round. Hinges shall be the lift-off pintle type, constructed of stainless steel; piano hinges are not acceptable. A restraining mechanism shall prevent opening more that 160o. Screwdriver-operated door latches shall be fitted at the top and bottom. In addition to the manufacturer’s certification label, each junction box shall have identification label attached to the box with 316 SS screws in a manner which will not invalidate the hazardous area certification. The label shall be constructed of white-black-white laminated plastic. The label shall include an engraved Tag No. An additional tag stating “Intrinsically Safe Circuits” shall be installed. This shall be blue-white-blue laminated plastic. b) Explosion Proof Explosion proof junction boxes shall be constructed from 316 SS. Boxes shall have at least four external mounting lugs, drilled with 10 mm fixing holes, and an 8 mm external earth lug. A full size removable stainless steel gear plate



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shall be fitted inside each box. Cables shall enter from the bottom, and 20% spare entries shall be provided. Cable entries shall be drilled and tapped to suit the required glands, and fitted with certified 316 SS plugs. Junction box lids shall have cast hinges integral to the box with stainless steel pins. Each junction box shall have an identification label, in addition the manufacturer’s certification label, attached with 316 SS screws in a manner, which will not invalidate the hazardous area certification. The label shall be constructed of white-black-white laminated plastic. Terminals shall be railmounted tunnel-type, made of melamine.



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INSTRUMENT PROCESS CONNECTIONS: Instrument process connections shall be as per relevant piping specifications. The nozzle length on vessels for temperature instruments on piping will be 200 mm (8”). For Thermowell installation, minimum pipe size shall be 4”. All threaded connections of the instruments shall be tapered. Connection for air or gas supply, transmission and control signals shall normally be internally threaded ¼” NPT. Instruments process measurement connections shall be threaded ½” minimum. Instrument isolation valves shall be installed as per the P & IDs and as detailed in the approved hook-up drawings. Take-offs from lines or vessels for all direct connected pressure instruments shall meet or exceed the line or vessel specification. All pressure instruments shall have an individual piping block valve and a 2, 3 or 5-valve manifold as appropriate, providing block, bleed and bypass. The only exception to this is for DP level transmitters with filled leg, which shall have block and bleed but no bypass capability. A maximum of two (2) pressure instruments may be connected to the same pressure tapping, so long as their function is not safety-related. Instruments for ESD or F&G systems shall each have their own individual tapping. Each pressure instrument shall have individual block. Each pressure transmitter shall be supplemented with a direct connected process pressure gauge on the same tapping. Connections to vessels, tanks and piping shall be the sizes and types listed in the following table. Generally, nozzles provided on vessels and tanks will be DN50 RF flange. The Contractor shall provide suitably rated flange adaptors to allow tubing connections where required.



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3.6.6 GENERAL REQUIREMENTS: 3.6.6.1

TAGGING AND NAME PLATES: The Contractor shall assign individual tag numbers in accordance with the Company’s established system to all instruments. The tag numbers shall in general be as follows: xxx xxx xxx xx Last 2 digits of reference P&ID Instrumentation Identification Number Name of the Instrument (FT, LT, etc.) Name of the Platform The tag number of every instrument shall appear on all relevant drawings and documents that pertain to the specific instrument. Nameplates and identification tags shall be provided to properly identify each piece of instrumentation / equipment including instruments, Junction boxes, bulkhead connections, cables, wiring, etc. All instruments shall have SS tag or nameplate of a permanent type with identification number and service description. All panel instrument nameplates shall be constructed of white laminated plastic plates with black engraved lettering and securely fastened with 316 SS screws. All front panel mounted equipment shall also be identified with a metal or plastic nameplate attached to the rear of the device, and easily visible via the rear access doors. All wiring, cables, tubes, multi-tube bundles, junction boxes and auxiliary equipment shall be suitably identified as per applicable codes and practices. Plastic adhesive tapes shall not be used for identification. All wiring shall be tagged with slip on or clip-on wire marker at both ends, with the wire number specified on the drawing. All site-mounted instruments, junction boxes, air/gas headers, tubing and wiring terminations shall be labeled or tagged in manner approved by the Company. Instruments shall be furnished with stainless steel nametags containing tag number, manufacturer’s name, model number and serial number. This tag shall be approximately 3” x 1” and shall be attached to the instrument with 16 gauge stainless steel wire.



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Labels shall be positioned directly on the equipment or immediately adjacent for best visibility. Positioning the label to one side shall be done only when other preferred positions are unavailable. Where label positioning is difficult, the Company’s representative shall determine the final position. Junction box labels shall be fitted on the lid in a central position. Typical instrument label details shall be as per Annexure – IX of this document.



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DOCUMENTATION: The contractor shall provide hard copies plus electronic copies on CD for all the documents.

3.6.6.2.1

Equipment Documentation: a)

The Contractor shall provide the following documents as a minimum: i) ii)

Operating philosophy of the system Proposed maintenance schedule of all major components, for the design life of the system, and their replacement requirements. iii) Equipment specifications iv) Catalogues v) Data sheets vi) Test certificates vii) Deviation schedule viii) System layout drawings ix) Functional schematic x) Bill of material / material take off xi) Instrument layout & cable tray routing drawings xii) Instrument calibration procedures xiii) Cable schedule xiv) Level Sketches xv) Instrument & Junction box location plans / layouts xvi) Loop schematics xvii) Interconnection diagrams xviii) Cable termination details xix) Installation standards / drawings xx) Pneumatic ESD loop and pneumatic FSD (Fusible Plug) layouts xxi) Servo / air supply header and distribution drawings xxii) Redundant cables list xxiii) Junction box wiring scheme xxiv) Field calibration and loop checking report xxv) MCT block sizing and arrangement drawing xxvi) As-built drawings b)

The Purchase Specification (PS) submitted for Company’s review / approval, shall have the following documents as a minimum: i)

Top sheet identifying the document number, and duly signed by the Contractor.


ii) iii) iv) v) vi) vii) viii) ix) x) xi) xii) xiii) xiv)


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Form B – Deviation schedule – duly signed by the Vendor and Contractor. (Typical, blank Form B is given in Annexure IV) Form C – List of Commissioning Spares – duly signed by the Vendor and Contractor (Typical, blank Form C is given in Annexure V) Form D – List of One year spares – duly signed by the Vendor and Contractor (Typical, blank Form D is given in Annexure VI) Form E – Inspection Requirement Table – duly signed by the Vendor and Contractor (Typical, blank Form E is given in Annexure VII) Instrument / Equipment specifications Catalogues Duly filled data sheets, signed by the Vendor and Contractor Test certificates Functional schematic (as applicable) Bill of material / material take off Instrument calibration procedures QA / AC Plan The Contractor shall provide a dossier of all hazardous area equipment, containing all information pertinent to the hazardous area work. The dossier shall include all necessary certificates, drawings, calculations, catalogue information, data and specification sheets, etc.

c)

Minimum 4 (four) sets of Dossier shall be provided to the Company.

d)

The contractor shall be responsible for the authenticity of the drawings & data provided by the vendor as sell as sub-vendor(s).

e)

Each vendor data items requested above must be identified by the Purchase Order number and equipment tag number located on the cover sheet or first page of said item and in the case of engineering drawings on each and every drawing.

f)

Any additional data/drawings required as a result of issuing supplements to a purchase order or during detailed engineering shall be furnished by Vendor and handled in the same manner as the original order.

g)

All drawings and literatures shall be in English language and in the Metric Measurement System.


h)

3.6.6.2.2


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The reproducible drawings, 279mm X 432mm (11” x 17”) size and full size are to be of such quality that clear legible prints can be made with Osalid type reproduction facilities.

Instrument Index: The contractor shall provide an Instrument Index. The index shall include the information listed below: Instrument Tag Number • • Service Description • Vessel / Line details • Process fluid • Operating pressure / temperature / flow / level parameters • Manufacturer / Model • Range / Calibrated Range Reference Piping And Instrument Diagram Drawing Number • • Data Sheet Number, With Latest Revision Location Of Instrument (i.e. Field, Control Panel) • • Remarks Column The instrument index shall form the basis for documenting all instrumentation and shall be listed in alphanumeric order of instrument tag number and shall contain all relevant information for each instrument. The index shall be based on Microsoft Access.

3.6.6.2.3

Instrument Data Sheet: A duly filled data sheet shall be provided for every item of instrumentation equipment, including those which are part of equipment packages, except those items which form part of the bulk material take-off. These specification sheets shall be according to relevant ISA standards and shall contain all information pertaining to a particular instrument including: • • • • • • •

Manufacturer Model Mechanical Details Electrical Details Materials Process Data (where required) Range


• •


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Hazardous area classification and certificate details (type of protection, certifying authority) Line or Vessel Number

When a number of items are identical in their requirements, these can be covered by a single specification sheet, provided all tag numbers are clearly listed. The Contractor shall submit his proposed data sheet for Company approval. Data sheets shall be generated using Microsoft Excel. 3.6.6.2.4

Instrument Calculations: The Contractor shall provide certified calculations for instruments, including those listed below: • Control valve sizing Regulator sizing • • Relief valve and rupture disc sizing Shutdown valve stroking time • • Flow element sizing • Restriction orifice sizing and stress analysis • Thermowell wade frequency • DP level transmitter ranging Intrinsically safe loop calculations, including cable, isolator and • field device parameters • Cable voltage drop • Diaphragm seal selection Analyzer fast loop time • These shall form part of the relevant Purchase Specification to be submitted during Detailed Engineering.

3.6.6.2.5

Flow Metering Report: The Contractor shall evaluate the flow metering requirements for the project and shall submit a report describing the selected metering methods, with supporting arguments and calculations.



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3.6.6.3

REVIEW AND APPROVAL:

3.6.6.3.1

The Contractor shall thoroughly review and approve vendor drawings for all instruments including sub-package items, DCS, ESD system, local pneumatic SDP, pneumatic ESD / FSD loop charging panel, etc., as applicable, before forwarding to Company for further review and / approval. Only the approved drawings duly stamped and signed by a competent engineer of the Contractor shall be sent to the Company.

3.6.6.3.2

All purchase specifications along with list of deviations, calculation sheets, offers of the vendor and all relevant correspondence shall be furnished for Company’s approval. Contractor shall not place the order without obtaining prior approval from the company.

3.6.6.3.3

Contractor shall prepare and furnish the list of all drawings / documents as enlisted in the bid document for Company’s review. The category of drawings / documents (i.e. whether to be reviewed / approved by the Company) shall be decided after award of Contract.

3.6.6.3.4

All vendors drawing shall be submitted for company’s review after the contractor’s engineering consultant approves them.



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3.6.6.4

VENDOR PRE-QUALIFICATION:

3.6.6.4.1

All equipment offered shall be of proven design. Similar equipment of the same vendor should have been in continuous satisfactory service on offshore installation for a minimum period of two (2) years and should be under Manufacture atleast for the last three (3) years, unless otherwise specified.

3.6.6.4.2

Contractor shall furnish list of all proposed vendors for Company’s approval. The contactor shall also furnish all pre-qualification documents for company’s review as and when asked for.

3.6.6.4.3

Approval of purchase specification does not absolve the contactor from supplying equipment of proven design as per the company specification.

3.6.6.4.4

The following is applicable to Vendors who are not listed in the Suggested Vendor List: •

The new Vendor shall furnish the past track record of similar material for similar service in offshore application along with details of clients, type of product, make, size, service, year of completion, and copies of any feedback information received from clients regarding functioning of equipment / material supplied.

•

Vendor shall furnish leaflets / catalogues / drawings / sketches of the particular product being supplied

•

Vendor shall furnish the details of their Indian Vendors (in case of foreign vendors) and sub-suppliers, viz. the name(s) of Manufacturer etc.

•

Quality assurance Manual shall be furnished for Company’ review which should include the schemes for product quality assurance, storage and traceability of products, quality assurance and quality control procedures.

•

Vendor / supplier or his sub supplier shall furnish the company’s profile with details of organogram & facilities.



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•

One set of pre-qualification documents on the product shall qualify only similar product of the same specifications and type.

•

The manufacturer / Vendor / sub-supplier shall be qualified based on results of these tests / past experience / details provided and Company’s decision in this regard shall be final and binding on the bidder.

•

Bidder / manufacturer shall note that for manufacturing of the quoted items, the same sources shall be utilized which were employed to manufacture the product on which pre-qualification tests are carried and approved.

•

Subsequent to qualification, a change of manufacturer, etc. shall not be permitted. In the event that the manufacture desires to effect any change in any of the above, the manufactures shall seek fresh qualification as indicated above.



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PREPARATION FOR SHIPMENT: Instruments or parts, which can be damaged during shipment, shall be packed separately in the original manufacturer’s boxes. Each package shall be identified with purchase order number and content list in a weatherproof envelope. All opening shall be sealed. Threaded connections shall be protected with forged steel or moulded plastic screwed plugs. All flanged openings shall be protected with wood or steel closures attached by proper bolting and sealed with a plastic compound to exclude foreign material from the interior and fully protect the flange faces. All mechanical or machined surfaces subject to atmospheric corrosion prior to installation on site shall be treated with an easily removable rust preventative. A desiccant shall be provided inside all enclosures to prevent moisture damage due to high humidity. Any plant component exceeding 40 Kg in weight shall be supplied with lifting lugs or eye bolts. The lugs or eyebolts should be positioned such that the component can be readily slung from a point over its centre of gravity. All items shall be properly packed and protected from damage during shipment. Any instrument on packaged equipment, which could possibly be damaged during shipment shall be disassembled and removed. The disassembled instruments shall be packed and shipped with the package or packaged equipment. All openings shall be suitably sealed. The electronic and electrical components removed from package-mounted panel shall be shipped independently. The shipping notice shall be written on the box or crate with red letters, such as “Handle with Care” / “Keep Dry” / “Fragile”, etc. A suitable desiccant shall be placed inside those control panels or junction boxes, which contain electronic or electrical components during shipment. Each crate, bag or package shall be clearly identified with the purchase order number and identification symbol. The Contractor shall be solely responsible for the adequacy of the Preparation for shipment in his Tender for review b y Company. Contractor shall also state in the Tender his recommendations for long term storage (up to 12 months) for both indoors and open air storage.



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It is Contractor’s responsibility to reassemble the instruments disassembled during shipment after the packages or packaged equipment are positioned and installed on site. i) ii) iii) iv)

Instrument commissioning records and calibration sheets. Purchase Order or extract thereof. A list of all applicable codes, standards and specifications. All drawings, “as built”. These shall include instrument installation details



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RECEIPT AND STORAGE: The Contactor shall develop a comprehensive plan for receipt, storage and release of all equipment released into his care, including items supplied by others or freeissued by the Company. This plan shall provide means to immediately establish the status and location of any item, which has been issued to the Contractor. The Contractor shall be fully responsible for equipment issued into his care, and shall provide secure facilities to provide a storage environment, which shall protect the equipment to the vendor’s requirements. Any equipment damaged after issue to the Contractor shall be repaired, reinstated or replaced, by the Contractor, at the Company’s discretion.



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ANNEXURE – I Instruments & Instrumentation Systems – Well Platform S. No.

ITEMS

Functional Specification No.

FIELD INSTRUMENTS 1

Differential Pressure Level Instruments

MR / OD / INST / FS / 3100

2

Level Gauges

MR / OD / INST / FS / 3101

3

Level Switch

MR / OD / INST / FS / 3102

4

Level Transmitter

MR / OD / INST / FS / 3103

5

Flow Switch

MR / OD / INST / FS / 3200

6

Flow Totalizer

MR / OD / INST / FS / 3201

7

Flow Transmitter

MR / OD / INST / FS / 3202

8

Orifice Plate

MR / OD / INST / FS / 3203

9

Positive Displacement Meter

MR / OD / INST / FS / 3204

10

Restriction Orifice Assembly

MR / OD / INST / FS / 3205

11

Senior Orifice Assembly

MR / OD / INST / FS / 3206

12

Rotameter

MR / OD / INST / FS / 3207

13

Turbine Flow Meter

MR / OD / INST / FS / 3208

14

Ultrasonic Flow meter

MR / OD / INST / FS / 3209

15

Water Cut Meter

MR / OD / INST / FS / 3210

16

Coriolis Flow Meter

MR / OD / INST / FS / 3211

17

Temperature Gauges

MR / OD / INST / FS / 3300

18

Temperature Switch

MR / OD / INST / FS / 3301

19

Temperature Transmitters

MR / OD / INST / FS / 3302

20

Differential Pressure Gauge

MR / OD / INST / FS / 3401

21

Pressure Gauge

MR / OD / INST / FS / 3402

22

Pressure Switch

MR / OD / INST / FS / 3403

23

Pressure Transmitter (Electronic)

MR / OD / INST / FS / 3404

24

Pressure Transmitter (Pneumatic)

MR / OD / INST / FS / 3405

25

Fire and Gas Detection System

MR / OD / INST / FS / 3500

26

Shut Down Panel

MR / OD / INST / FS / 3501

27

Telemetry Interface Cabinet

MR / OD / INST / FS / 3502

28

Instrumentation for Package Equipment

MR / OD / INST / FS / 3503



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29

Hi-Lo Pilot (Pneumatic / Electric)

MR / OD / INST / FS / 3600

30

PIC (Pneumatic / Electric)

MR / OD / INST / FS / 3601

31

Portable Data Logger

MR / OD / INST / FS / 3602

32

Recorder (Electronic)

MR / OD / INST / FS / 3603

33

Recorder (Pneumatic)

MR / OD / INST / FS / 3604

34

Portable Calibrator

MR / OD / INST / FS / 3605

35

Smart Communicator

MR / OD / INST / FS / 3606

36

Filter Regulator

MR / OD / INST / FS / 3607

37

Control Valves

MR / OD / INST / FS / 3700

38

Safety Relief Valves

MR / OD / INST / FS / 3701

39

Self Actuated Pressure Control Valve

MR / OD / INST / FS / 3702

40

Deluge Valve

MR / OD / INST / FS / 3703

41

Chlorine Analyzer

MR / OD / INST / FS / 3800

42

Corrosion Analyzer

MR / OD / INST / FS / 3801

43

Dew Point Analyzer

MR / OD / INST / FS / 3802

44

Dissolved Oxygen Analyzer

MR / OD / INST / FS / 3803

CONTROL ROOM INSTRUMENTS: 45

Distributed Control System (DCS)

MR / OD / INST / FS / C100

46

Programmable Logic Controller (PLC)

MR / OD / INST / FS / C101

Series 31_ _ represents Level Instruments Series 32_ _ represents Flow Instruments Series 33_ _ represents Temperature Instruments Series 34_ _ represents Pressure Instruments Series 35_ _ represents Systems Instruments Series 36_ _ represents Miscellaneous Instruments Series 37_ _ represents Valves Series 38_ _ represents Analyzers Series C1_ _ represents Control Room Instruments Note: The list of specific Functional Specifications applicable for RSPPM Project is indicated under ‘Scope of Work – Instrumentation’.



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ANNEXURE – II: PIPING CLASS S. NO

MATL. STNO

1 2 3 4 5 6

A1 B1 D1 E1 F1 XFI

ANSI CLASS LBS 150 300 600 900 1500 1500

7 8 9 10

A2 B2 D2 E2

150 300 600 900

11 12 13 14 15 16 17

A3 B3 A4 A5 A6 A7 A8

150 300 150 150 150 150 150

18 19 20 21 21(i)

A9 B9 D9 E9 F9

150 300 600 900 1500

22 23 24 25 26

A10 B10 D10 E10 F10

150 300 600 900 1500

27 28 29 30 31

A11 B11 D11 E11 F11

150 300 600 900 1500

TEMP RANGE 0 C

SERVICE

PIPE MATERIAL

HYDROCARBON LIQUID AND VAPOUR, INJECTION WATER

CS

16/371

GLYCOLITHERMINOL

CS

16/121 TO 66 TO 75 TO 454 TO 82 TO 66

INSTRUMENT AIR UTILITY AIR POTABLE WATER SALT WATER GAS TURBINE EXHAUST SOLDIUM HYPOCHLORITE SALT WATER SEWER

TO 454

LUBE OIL / SEAL CHEMICAL

SS 316

TO 425

BREATHING AIR

SS316

TO 454

HYDRO CARBON LIQUID & VAPOUR (SOUR SERVICE)

SS 316L (NACE)

TO 121


DUPLEX STEEL

16/260 16/93

TO 149

CS GALV. CS GALV. 90/10 CuNi SS 316 CPVC CS GALV



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ANNEXURE – II (CONTD.)

S. NO

MATL. STNO

32 33 34 35

PA1 PB1 PD1 PE1

ANSI CLASS LBS 150 300 600 900

TEMP RANGE 0 C

36

PXF1

1500

16/120

37

PF1

1500

38 39

XG1 XG1N

AP15000 AP15000

40 41 42 43 44 45 46 47 48 49

A1N B1N D1N E1N F1N A1H PA1N PB1N PD1N PE1N

150 300 600 900 1500 150 150 300 600 900

50

PF1N

1500

51 52 53 54 55

PA11 PB11 PD11 PE11 PF11

56 57 58

A12 A13 A14

16/120

SERVICE

HYDRO CARBON LIQUID & VAPOUR, INJECTION WATER (FOR LAUNCHER/RECEIVERS ONLY)

PIPE MATERIAL

CS

CS

16/260

HYDRO CARBON LIQUID & VAPOUR, (FOR LAUNCHER/RECEIVERS ONLY) - DO -

16/60 16/60

ACIDIZATION ACIDIZATION (SOUR SERVICE)

CD CS

16/260


16/260

HP FLARE, LP FLARE

16/261

HYDRO CARBON LIQUID & VAPOUR (SOUR SERVICE) FOR LAUNCHER / RECEIVERS ONLY

CS (NACE)

150 300 600 900 1500

16/121

HYDRO CARBON LIQUID & VAPOUR (SOUR SERVICE) FOR LAUNCHER / RECEIVERS ONLY

DUPLEX STEEL

150 150 150

16/175 99oC 66oC

CHEMICALS POTABLE WATER SALT SEWER

CS

CS (NACE + ANNEX-I) CS

TITANIUM COPPER PVC



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ANNEXURE – III: TEST AND CALIBRATION FORM LOOP NO ITEM NOS

LOCATION MODULE SYSTEM

DESCRIPTION (ABBREVAIATION)

DATE

TEST EQUIPMENT USED

CONTRACTOR AND PERSONAL MAKING TEST

TO SPECS INSTALLED PIPED/WIRED TO SPECS INSTALLED PIPED/WIRED CLIBRATE TO SPECS INSTALLED PIPED/WIRED CLIBRATE TO SPECS INSTALLED PIPED/WIRED CLIBRATE

TRANSMITTER

CONTROL VALVE

RECORDER

TO SPECS INSTALLED PIPED/WIRED CLIBRATE

RECORDER INDICATOR


ALARM SWITCHES


REMARKS

PRIMARY ELEMENT


ACCESSORIES

LOOP CHECK



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ANNEXURE – IV: PNEUMATIC INSTRUMENT BRANCHING CONNECTIONS



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ANNEXURE – V: FORM B – DEVIATION LIST (TYPICAL) Requisition for: Project: S. No.

Document Clause No.

Requirement

Vendor’s deviation with reasons

Notes (If any):

Vendor’s Signature, Seal & Date

Contractor’s Signature & Date (This form shall be signed by Vendor and Contractor. In case there are no deviations, “NO DEVIATIONS” shall be written across the table)



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ANNEXURE – VI: FORM C – LIST OF COMMISSIONING SPARES (TYPICAL) Requisition for: Project: S. No.

Part Number

Description

Quantity

Unit price *

Total price *

* CURRENCY Notes (If any):

Vendor’s Signature, Seal & Date Contractor’s Signature & Date

(The Vendor should state in this form, a list of commissioning spares and related information, which in his opinion are essential for the purpose of commissioning of the relevant item. This form shall be signed by Vendor and Contractor.)



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ANNEXURE – VII: FORM D – LIST OF ONE-YEAR SPARES (TYPICAL) Requisition for: Project: S. No.

Part Number

Description

Quantity

Unit price *

Total price *

* CURRENCY Notes (If any):

Vendor’s Signature, Seal & Date

Contractor’s Signature & Date

(The Vendor should state in this form, a list of spares, which in his opinion are essential for one year operation / maintenance of the relevant item. This form shall be signed by Vendor and Contractor.)



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ANNEXURE – VIII (Contd.)

CHART 1

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Design Criteria Instrumentation

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