Request For Quotation THIS IS NOT AN ORDER - Orpic 990000… · Request For Quotation Collective No: 9900009783 Orpic Aromatics LLC Vendor Code: 1000 ... API RP 551-1993: Process

Request For Quotation

Collective No: 9900009783 Orpic Aromatics LLC

Vendor Code: 1000

Vendor Name: Orpic

Vendor Name: Orpic

City:

Country:

P.O. Box: PC:

Contact Person:

Email Address:

Tel No:

Information

THIS IS NOT AN ORDERSubmission Date: 01.01.2017Floating Date: 25.12.2016P\C Officer: Abdulaziz Al GhaithiTelephone:Fax:Email: ABDULAZIZ.ABDULLAH.ALGHAITHI@OInternal Number: 6000023592

Submission Date & Location

Kindly submit your Quotation on or before 01.01.2017 by 23:59:59 hrs.

If supplier copies the procurement officer while submitting his offer, his bids/offer will be rejected.

Submission Details

Quotations and technical submissions (if applicable) shall be submitted by email to [email protected]. The emailsubject line shall include the RFQ Collective Number. For any further clarifications, please contact the respectiveprocurement officer on the Email printed above. Failure to comply with any of the submission instructions shall result indisqualification of the Quotation.

For Payment concerns, please submit original invoice to Email : [email protected]

[Bidder to complete the following declaration in RFQ submission]

Dear Procurement Officer

Having carefully examined the Request For Quotation (RFQ) and its attached Instructions to Bidders and GeneralConditions for Purchases and Minor Services, we offer to supply the Goods and Services for the Prices submitted in thisQuotation.

We confirm that our Quotation is made in full conformity with the RFQ, the Instructions to Bidders, specifications, GeneralConditions for Purchases and Minor Services and all Clarifications and Addenda issued during the RFQ period.

If our Quotation is accepted and a Purchase Order or Service Order issued by Orpic we agree to deliver the Goods andServices in full accordance with the RFQ and our Quotation.

We agree to abide by this Quotation for a period of ninety (90) days from the Submission Date and it shall remain bindingupon us and may be accepted at any time before the expiration of this period.

Dated _ _ _ _ _ _ _ _ _ .

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Signed _ _ _ _ _ _ _ _ _ _ _ _ _.

Name: _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .

Title: _ _ _ _ _ _ _ _ _ _ _ _

for and on behalf of_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _

Order Currency:______________

ItemNo.

Material Description Quantity UOM UnitCost

LineCost

10 Pressure Transmitter A21-PT-200 1 EA20 Diff Pressure Transmitter A21-PDT-250 1 EA

(A)Ex-Works Costs(B)CIF Costs

(C) Custom Duty(D) COO Charge

(E) Total Cost (B+C)Total(In words):

Estimated Weight

Page 2 of 10

DOCUMENTS TO BE SUBMITTED: Bidder to Submit and confirm following alongwith the bid:

1. Tenderer Experience 2. Bidder to confirm complete compliance scope of supply. 3. Bidder to submit quality documents alongwith the bid 4. Bidder to comply with delivery period of 8 weeks DDP Orpic Sohar refinery

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JOB No. JGC DOC. No. REV.

0-3100-25 S-000-1373-001 R

DATE 12 − Nov − 2003 SHEET 1 OF 8

PREP’D J. Kim/ F. Edono

CHK’D S. Watanabe

APP’D H. Furuta

GENERAL SPECIFICATION

FOR

TRANSMITTERS

SOHAR REFINERY COMPANY L. L. C.

SOHAR REFINERY PROJECT

SOHAR, SULTANATE OF OMAN

Reference ITT Doc. No. Rev

N/A

REV. DATE PAGE DESCRIPTION PREP’D CHK’D APP’D

0 12-Nov-03 All For Approval J.K / F.E S.W H.F

R 22-Mar-03 All For Construction (as per JY-OY-M-20281) T.K / F.E S.W H.F

PROJECT SPECIFICATION

Sohar Refinery Company SOHAR Refinery Project

FOR CONTRUCTION

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JOB CODE: 0-3100-25Sohar Refinery Company SOHAR Refinery Project

DOC NO: S-000-1373-001 rev.R General Specification for Transmitters SHEET : 2 of 8

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CONTENTS

1 GENERAL ......................................................................................................................................................3 1.1 Scope ........................................................................................................................................................3 1.2 References ................................................................................................................................................3 1.3 Environmental Conditions........................................................................................................................3 1.4 Unit of Measurement ................................................................................................................................3 1.5 Flange and Flange Face Finish .................................................................................................................4 1.6 General Design Requirement....................................................................................................................4

2 PRESSURE & DIFFRENTIAL PRESSURE TRANSMITTER requirements.........................................4 2.1 Differential Pressure Type Flow Transmitter ...........................................................................................4 2.2 Differential Pressure Type Level Transmitter ..........................................................................................5 2.3 Pressure Transmitter .................................................................................................................................5 2.4 Differential Pressure Transmitter .............................................................................................................5 2.5 Performance..............................................................................................................................................5

3 ELECTRICAL REQUIREMENT ................................................................................................................6 3.1 Electrical hazardous classification............................................................................................................6 3.2 Signal transmission...................................................................................................................................7 3.3 Enclosure ..................................................................................................................................................7 3.4 Electrical connection ................................................................................................................................7

4 Accessories ......................................................................................................................................................7 4.1 Mounting Bracket.....................................................................................................................................7 4.2 Local Indicator..........................................................................................................................................7 4.3 Valve Manifold.........................................................................................................................................7

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1 GENERAL

1.1 Scope

This specification defines the minimum requirements for design, manufacturer and features of the

electronic transmitters for Sohar Refinery Project.

1.2 References

The latest edition of the following standards as of 19 May 2003 shall be referenced, unless otherwise

specified.

(1) American Petroleum Institute API RP 551-1993: Process Measurement Instrumentation;

Section 2-FLOW Section 3-LEVEL Section 4-PRESSURE

(2) National Association of Corrosion Engineers NACE MR0175-2002: Sulfide Stress Cracking Resistant Metallic Materials for Oilfield Equipment

(3) International Electrotechnical Commission

(a) IEC 60079-0: Electrical apparatus for explosive gas atmospheres, part-0; General (b) IEC 60079-1: Electrical apparatus for explosive gas atmospheres, Part-1; Flameproof enclosure ‘d’ (c) IEC 60079-11: Electrical apparatus for explosive gas atmospheres, Part-11; Intrinsic safety ‘i’ (d) IEC 60079-14: Electrical Installation of hazardous areas (e) IEC 60529: Degree of protection provided by enclosure

1.3 Environmental Conditions

All instruments shall be suitable for installation in the climatic conditions specified below and shall be tropicalized as per the manufacturer standard procedure. All parts subject to dust, moisture, insect, corrosion, etc. shall be treated with a suitable coating to inhibit such attack in a salt laden, marine atmosphere. (1) Ambient design temperature max./min.: 47.5 (dry bulb temp.)/ 5 ℃ (Min. record

temperature is 3.5℃) shall be used for design. It shall be considered that the surface temperature does exceed the equipment design temperature in particular when exposed to direct sunlight.

(2) Relative humidity: max. / min. : 100% / 6% (3) Location : Sea Coast

1.4 Unit of Measurement

The units of measurement shall be as follows:

Temperature ℃ Mass kg/h, ton/h, ton/d Liquid m3/h

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Vapor Nm3/h (at 0℃, 1.013 bara) Pressure (gauge) barg, mbarg Pressure (absolute) bara, mbara Density kg/m3 Viscosity Cp

1.5 Flange and Flange Face Finish

All flanges shall conform to ANSI/ASME B16.36. Face finish shall be in accordance with ASME B16.5 or B16.47 as follows: Raised Face and Flat Face The gasket contract surface shall be serrated in either a concentric or continuous spiral in accordance with ASME B16.5 Para. 6.4.4.3 or B16.47 Para. 6.1.4.2. The resultant of face shall be in a roughness between Ra 3.2 and Ra 6.3µm (125µin. to 250 µin.)

1.6 General Design Requirement

(1) The material of the transmitter body shall be Cadmium plated carbon steel or 316 SS,

diaphragm material shall be 316 stainless steel as minimum, unless otherwise specified in the instrument specification sheets.

(2) For absolute, gauge pressure transmitters and differential pressure transmitters, the transmitter

body shall have a static pressure rating of 105 barg or 150% of the sensor upper range limit (URL) at the operating temperature, whichever is greater.

(3) For pressure transmitters and differential pressure transmitters, any resultant zero shifts shall be

limited to less than 1 % of the calibrated span of the transmitter. (4) Transmitters shall be with 1/2" NPT screwed process connections. (5) All transmitters shall have adjustable zero and span. (6) All instruments shall be factory calibrated for the specified range.

2 PRESSURE & DIFFRENTIAL PRESSURE TRANSMITTER REQUIREMENTS

2.1 Differential Pressure Type Flow Transmitter (1) Basically square root flow signals from the field shall be linearized in the flow transmitter and

not in DCS, except where the square root signal is required in calculations or in control (e.g. antisurge control).

(2) Unless otherwise specified in licenser’s specification, based on linear scale, the flowmeters

shall be ranged for a reading at:

(a) Maximum flow between 90% and 98% of the scale.

(b) Normal flow between 70% and 75% of the scale.

(c) Minimum flow shall not be below 30% of the scale for all applications other than those referred to above.

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2.2 Differential Pressure Type Level Transmitter (1) Differential Pressure Level Instruments shall be generally used for level measurement, except

for interface level measurement. (2) Where material is liable to separate, solidify or deposit in impulse lines, the lines should be

purged or trace heated as appropriate. Alternatively, direct mounting diaphragms may be used. Adequate mechanical protection for capillaries shall be provided. The effect of blockages or capillary failure on the integrity of process control and safety systems shall be assessed.

(3) The Contractor will specify the appropriate seal liquid in the impulse line where it is required,

which requirement will be specified on the individual instrument specification sheets. (4) A dry or gas-purged reference leg should be used for applications where it is impractical to

maintain a filled reference leg, (e.g. in vacuum systems). (5) The instrument range, suppression or elevation depends on the physical dimensions of the

installation and densities of the various fluids. (6) The required instrument range and elevation or suppression shall be specified in mbar.

2.3 Pressure Transmitter (1) In services that are corrosive to available transmitter internals, where plugging may occur, or

high viscosity fluids are encountered, diaphragm seals compatible with the process fluid shall be used to isolate the transmitter internals from the process fluid.

(2) For absolute and gauge pressure transmitters, measuring elements shall be capable of

withstanding pressure up to that of the static pressure rating without damage to the element. (3) Pressure instruments shall have over-range (for pressure) and under-range (for vacuum)

protection to prevent mechanical damage or shift in calibration. Where necessary, the over-range protection shall cover and exceed the relevant relieving pressure of safety relief valve.

(4) Output signals from the field shall be linearized in the pressure transmitter.

2.4 Differential Pressure Transmitter (1) In services that are corrosive to available transmitter internals, where plugging may occur, or

high viscosity fluids are encountered, diaphragm seals compatible with the process fluid shall be used to isolate the transmitter internals from the process fluid.

(2) Differential pressure transmitters shall be installed on the ground level or on the platform with

2 inch pipe stanchion and impulse line length to be minimized to avoid a measurement error due to any specified gravity differences in the high and low impulse lines.

2.5 Performance

(1) Response time and Update Rate

(a) For transmitter used in process control loops, response time and update rate shall be used in determining transmitter performance and both criteria shall be considered in the selection of the equipment. Response time is defined as the time it takes for the transmitter output to reach 63.2% of the actual step change in pressure. The response time includes any dead time associated with the initial step change in input signal and the transmitter output actually changing. Update rate is defined as the time interval between updates of the transmitted process measurement value.

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(b) As a minimum, pressure and differential pressure digital transmitters used in process control loops shall meet the following requirements.

a) Transmitter with an upper range limit of 76 mbar or less shall have a response time

of 600 milliseconds or less. Other transmitters shall have a response time of 500 milliseconds or less.

b) Transmitters shall have an update rate at least as fast as the table below. The

table is based upon a transmitter update rate at least twice as fast as the proportional, integral, derivative (PID) controller algorithm execution rate.

Control Type Output Signal update rate Flow (∆P), Pressure, Differential Pressure Level (∆P)

125 milliseconds 500 milliseconds

Faster update rate/response time transmitters may be required for certain applications such as compressor antisurge control systems. Slow update rate/response time transmitters may degrade control performance.

(2) Process Measurement Communication Protocol

The communication protocol shall not prevent the instrument from measuring and transmitting the process pressure or differential pressure, except when the instrument is being configured.

(3) Failure Mode

The transmitter electronics shall be capable of monitoring its performance during normal operation. The diagnostics shall be able to detect both an input sensor failure and transmitter electronics failure. The sensor or electronics failure shall be transmitted to the host system (e.g. DCS, PLC) using a low milliamp signal (as below) or by using a HART signal, depending on the capabilities of the host system.

The transmitter shall be provided with burn-out protection. Alarm (burn-out) and saturation current limits shall be, NAMUR compliant, in accordance with the following:

Fail low: I < 3.6 mA Fail high: 21.0 mA < I < 23.0 mA Low saturation: I = 3.8 mA High saturation: I = 20.5 mA

(4) Electronic Damping

The transmitter shall be capable of setting the electronic damping of the output to zero. Damping values shall be set to zero, unless specified otherwise.

(5) Vendor Factory Calibration

The instrument calibration shall be completed by the vendor prior to shipment of the instrument. Only calibration via a smart communicator is not acceptable for vendor’s factory calibration.

(6) HART host system Vendor shall state the compatibility of hart communication with Yokogawa PRM and other equivalent systems.

3 ELECTRICAL REQUIREMENT

3.1 Electrical hazardous classification

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The basis for area classification shall be in accordance with the provisions of the IP/IEC. All outdoor electrical instrumentation shall be certified for the area classification. (1) All electrical devices, electronic instrumentation and wiring shall be suitable for installation in

the relevant electrical area classification. (2) Equipment located in hazardous area shall be certified by internationally recognized

organizations to, LCIE, INERIS, TIIS, EECS, FM, UL, etc. The use of the other nationally accepted standards shall be subject to approval by the Purchaser.

(3) When the hazardous areas are classified, instruments shall be EExi or Exi type. Other type of

protection, such as EEx”d” and EEx”n”, shall be used for by exceptions, and require OWNER approval. All outdoor electrical instrumentation located in non-hazardous areas shall be suitable for a zone 2 area, minimum gas group IIC and temperature class T3. Instead of certification, use of manufacturer's declaration on basis of IEC 60079.14 in zone 2 areas may be used in special cases, subject to OWNER approval. EEx”i” instrumentation in non-hazardous areas are not required to utilize barriers

3.2 Signal transmission

All electronic transmitters shall be smart type and 4 to 20mA with digital communication protocol superimposed (HART) except for service where the high-speed response is required, non-smart type transmitter may be used for compressor anti-surge control.

3.3 Enclosure All outdoor electrical instruments shall be NEMA 4X or IP 55 as minimum. Requirements for protection of equipment against direct sunlight shall be assessed at site.

3.4 Electrical connection All electrical connection size shall be of M20 x 1.5(female) with ISO metric size thread.

4 ACCESSORIES 4.1 Mounting Bracket

All transmitters and remote indicators shall be furnished with a universal mounting bracket for 2" pipe stanchion.

4.2 Local Indicator All instruments shall be provided a digital type integral indicator unless otherwise specified on the instrument specification sheets.

4.3 Valve Manifold The manifold valves shall be supplied by JGC for the following based, unless otherwise specified on the instrument specification sheets. For high-pressure service (900# or 1500#) and pressure lead piping application, piping valves shall be used. Instrument type Manifold type Differential pressure flow transmitters (FT) 5 valves manifold Differential pressure transmitters (PDT) 5 valves manifold (note 1) Differential pressure transmitters (PDT) 4 valves manifold (note 2) Differential pressure level transmitters (LT) 4 valves manifold (note 3) Pressure transmitters (PT) 2 valves manifold Note 1. For low differential pressure service.

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Note 2. For general service, 5 valves manifold with an equalizing valve can be used where

contamination or a hazardous condition will not result. Note 3. Without equalizing valve.

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JOB No. JGC DOC. No. REV.

0-3100-25 S-000-1370-001 R

DATE 23 − Oct − 2003 SHEET 1 OF 31

PREP’D S. Watanabe

CHK’D H. Furuta M. Tabuse

APP’D H. Furuta K. Hirabuki

GENERAL SPECIFICATION

FOR

INSTRUMENTATION

SOHAR REFINERY COMPANY L. L. C.

SOHAR REFINERY PROJECT

SOHAR, SULTANATE OF OMAN

Reference ITT Doc. No. Rev

S-000-1370-001 B

REV. DATE PAGE DESCRIPTION PREP’D CHK’D APP’D

0 23 Oct 2003 All For Approval S.W H.F / M.T H.F / K.H

R 14 Apr 2004 All For Construction (JY-OY-M-20288) T.K S.W H.F

PROJECT SPECIFICATION

Sohar Refinery Company SOHAR Refinery Project

FOR CONSTRUCTION

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DOC NO: S-000-1370-001 rev.R General Specification For Instrumentation SHEET : 2 of 31

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CONTENTS

1 INTRODUCTION......................................................................................................................................... 3 2 APPLICABLE DOCUMENTS .................................................................................................................... 3 3 INSTRUMENT REQUIREMENTS............................................................................................................ 4 4 CONTROL BUILDINGS ............................................................................................................................. 8 5 CONTROL AND MONITORING SYSTEM ........................................................................................... 11 6 LOCAL CONTROL PANELS................................................................................................................... 13 7 TEMPERATURE INSTRUMENT............................................................................................................ 14 8 FLOW INSTRUMENT .............................................................................................................................. 15 9 LEVEL INSTRUMENT ............................................................................................................................. 16 10 PRESSURE INSTRUMENT...................................................................................................................... 18 11 VALVES ...................................................................................................................................................... 21 12 ANALYZER AND SAMPLING SYSTEM............................................................................................... 21 13 INSTRUMENT CONSTRUCTION MATERIAL ................................................................................... 21 14 INSTALLATION OF INSTRUMENT...................................................................................................... 23 15 EARTHING SYSTEM................................................................................................................................ 26 16 DOCUMENTATION.................................................................................................................................. 27 17 SPARE PARTS ........................................................................................................................................... 27 18 APPENDIX – 1 LIST OF REFERENCED DOCUMENTS ............................................................... 28 19 APPENDIX – 2 NAME PLATE............................................................................................................ 31

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1 INTRODUCTION 1.1 PURPOSE

The purpose of this specification, together with the Licensor standard specifications, drawings, Industrial codes and standard, is to define the general requirements for instrumentation for Sohar Refinery Project.

1.2 SCOPE

This specification provides the general instrument requirements for the project. For more detailed information, the relevant project specifications and Licensers’ documents shall be referred to.

1.3 CONFLICTS and DEVIATIONS

If any inconsistency or conflict exists between this specification and other Licensors’ documents, industrial standards or drawings, the following precedence will be applied: (1) Governmental or Local Authority regulations. (2) General Specification for Instrumentation (S-000-1370-001). (3) Other Instrument Specifications as referenced in this Specification, listed below. (4) Licensors’ documents as part of the Project Specification. (5) Industrial International Codes and Standards. Where a conflict between the above documents might exist, the conflict shall be brought to Owner. Owner shall resolve the conflict in case by cases.

2 APPLICABLE DOCUMENTS 2.1 The following documents shall apply as a part of the instrument design and engineering basis together

with this specification.

- S-000-1370-002 Instrument and Control Philosophy - S-000-1371-001 Specification for DCS - S-000-1371-002 Specification for ESD and FGS - S-000-1371-004 Product Blending Control System - S-000-1371-005 Specification for Online ESD Valve Testing - S-000-1371-201 Specification for Cabinet and Rack Design - S-000-1372-001 Specification for Integrated Control and Information Management System (ICIMS) - S-000-1374-101 General specification for Control valves - S-000-1374-201 General specification for On-off valves - S-000-1375-001 Specification of Analyzers - S-000-1377-002 Specification for Metering System

- UOP licensing documents - TECHNIP licensing documents for Hydrogen Generation Unit (GHU) - STORK licensing documents for Sulfur Recovery, Tail Gas Treating Unit (SRU and TGU) - IFP issued documents for Total’s Selective Hydrogenation Process Unit and Gasoline HDS Unit

(TSHP and GHDS) - NESTE issued documents for TAME unit (TAME) - Other industrial Codes and Standards such as API, ISA etc. referred to in this specification

2.2 The latest edition of the standards as of 19 May 2003 shall be applied unless otherwise specified.

Standards, codes, standard drawings and specifications referred to in this specification are listed on Appendix 1 "List of Referenced Documents". Abbreviations for the standard are as listed below.

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AGA American Gas Association AISI American Iron and Steel Institute ANSI/ASME American National Standards Institute/American Society & Mechanical

Engineering API American Petroleum Institute ASTM American Society for Testing and Material BASEEFA British Approvals Service for Electrical Equipment in Flammable Atmospheres BS British Standard CENELEC European Committee for Electrotechnical Standardization DIN Deutsches Institute für Normung EEMUA Engineering Equipment and Material Users Association EIC Energy Industrial Council FCI Fluid Controls Institute FM Factory Mutual IEEE Institute of Electrical Electronic Engineers IEC International Electrotechnical Commission IP Institute of Petroleum ISA The Instrumentation, Systems and Automation Society ISO International Organization for Standardization JIS Japanese Industrial Standard NACE National Association of Corrosion Engineering NEC National Electric Code NEMA National Electrical Manufacturers Association NESC National Electrical Safety Code NFPA National Fire Protection Association UL Underwriter’s Laboratories

3 INSTRUMENT REQUIREMENTS 3.1 GENERAL 3.1.1 Installation environment

Instruments shall be suitable for installation in the climatic conditions specified below and shall be tropicalised as per the manufacturer standard procedure. All parts subject to dust, moisture, insect, corrosion, etc. shall be treated with a suitable coating to inhibit such corrosive attack. A sunshade (304 stainless steel) or a suitable cooler shall be provided where the instrument, local panels, etc. are exposed to direct sunlight. Pneumatic instruments (actuators), gauges, etc. do not require a sunshade. (1) Ambient design temperature - max ./ min. : 47.5 (dry bulb temp.)/ 5 deg C

Min. record temperature is 3.5 degC shall be used for examination the impact to transportation with high pour point field. It shall be considered that the ambient temperature does exceed the design temperature in particular when exposed to direct sunlight.

(2) Relative humidity - max. / min. : 100/ 6 %

(3) Maximum wind - 22.9 m/sec Wind direction - NNW

(4) Barometric pressure - max. /min. : 1026/ 990 mbar

(5) Earthquake - Nil

(6) Location - Sea Coast

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3.1.2 Electrical hazardous classification The basis for area classification shall be in accordance with the provisions of the IEC. All outdoor electrical instrumentation shall be certified for the area classification. (1) All electrical devices, electronic instrumentation and wiring shall be suitable for installation in

the relevant electrical area classification. (2) Equipment located in hazardous area shall be certified by internationally recognized

organizations to LCIE, INERIS, TIIS, EECS, FM, UL, PTB, BASEEFA, KEMA, etc. The use of other nationally accepted standards shall be subject to approval by Contractor.

(3) When the hazardous areas are classified, instruments shall be EExi or Exi type. Other type of

protection, such as EEx”d” and EEx”n”, shall be used by exceptions, and require Owner approval. All outdoor electrical instrumentation located in non-hazardous areas shall be suitable for a zone 2 area, minimum gas group IIC and temperature class T3. Instead of certification, use of manufacturer's declaration on basis of IEC 60079.14 in zone 2 areas may be used in special cases, subject to Owner approval. EEx”i” instrumentation in non-hazardous areas are not required to utilize barriers.

(4) Purged and pressurized air protection stipulated by NFPA, BS, etc. can be applied for

enclosures such as local panels in hazardous location.

(5) Instruments type of protection for Fire and Gas System (FGS) shall be Ex”d” or EEx”d” type. 3.1.3 All outdoor electrical instruments, local panels and Junction Boxes (J.B) shall be NEMA 4X or IP 55

as minimum. Requirements for protection of equipment against direct sunlight shall be assessed at site by Contractor and Sub-contractor.

3.1.4 One style of tube fittings, i.e. double ferrule type compression fitting, shall be selected and used

through-out the plant, e.g. Parker Hannifin or equivalent with Owner’s approval. 3.1.5 As a minimum, all wetted parts of instrumentation shall be 316SS, unless specified differently in the

instrument specification sheets. 3.1.6 Instrument installation will be per API RP 551 (1993). All process connections shall have a piping

root valve. 3.1.7 All equipment and materials shall be new and supplied from the approved instrument vendor list.

Many duplicated items existing in the market should be avoided. 3.1.8 All instrument systems (Control, Monitoring and ESD systems) shall be provided from the latest field

proven product line at the time of purchase order issue. Use of equipment manufactured with unknown standards shall be avoided. The latest debugged software version shall be applied at the time of frozen detailed design, and the latest debugged software release shall be used during installation and commissioning.

3.1.9 Signal transmission

(1) Pneumatic instruments shall have a standard air signal of 0.2 to 1.0 barg.

(2) Electric instrument signals shall be 4 to 20 mA DC except some level instruments (e.g. tank gauges), positive displacement meters, turbine meters and quality analyzers, etc.

(3) Instrument circuit shall be 24VDC.

3.1.10 Air supply and output gauges shall be provided for all instruments consuming air. 3.1.11 Filter regulator assembly shall be provided for all instruments requiring an air supply and shall be

designed for 4-11 barg inlet air pressure.

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3.1.12 All automatic-manual air transfer switches shall be integrally mounted, preferably internally. They shall be 4 positions for large case (conventional type) instruments. Miniature pneumatic and electronic controllers shall have the number of switch positions required for bumpless transfer from automatic to manual control and vice-versa.

3.1.13 All field transmitters shall be SMART type of 4-20 mA with HART communication protocol except

for service where the high speed response is required, non-smart type transmitters should be used, e.g. for the compressor anti-surge control that is subject to approval by Owner. All transmitters shall have an integral digital indicator. 10 handheld terminals for the HART instruments shall be provided which will be used during commissioning, installation and maintenance.

3.1.14 24 VDC shall be used for trip or sequential initiation or activation device. 3.1.15 Lighting and sockets in Supplier panels or cabinets, if necessary, shall be powered from Non-UPS at

240VAC, 50 Hz single phase. All other instruments shall be powered from UPS at 240VAC, 50Hz single phase. Where the panels or field circuits require lower voltage levels, these shall be generated via power supply units provided as part of the package. Emergency lighting will be provided outside of local cabinets.

3.1.16 All panel circuits shall be suitably protected against over current, with suitable isolation as necessary

for testing and maintenance. All external circuits powered by the equipment shall be individually isolated and protected at source.

3.1.17 All wiring and cable cores shall be suitably identified at the terminal points, e.g. ferruling. The

identification system is described in D-000-1378-001 “Instrument Typical Installation”. 3.1.18 Terminal blocks with “Weidmuller SAK series” disconnect type and a fuse for each signal shall be

provided inside panels and all wirings to/ from the panel shall be terminated on these terminal blocks. At least 20% spare terminals shall be provided with any instrument panels/cabinets, junction boxes and local panels.

3.1.19 All relays installed in outdoor local panels or boxes shall be hermetically sealed type or gold plated

contact type. 3.1.20 Factory acceptance test (FAT)

Owner will attend the following FAT: (1) DCS (2) ESD (3) Fire and Gas System (FGS) (4) Metering Systems (5) Tank Gauge Systems (TGS) (6) MOV Systems (7) Analyzers (8) Truck Loading Automation Systems (TLAS) (9) Compressor Control System including Anti-Surge Controller (10) Control Valves (11) ESD Valve Testing System

3.1.21 Control and trip devices shall not share the same measurement bridle where the process fluid has a

risk of fouling. 3.1.22 Generally all trip transmitters shall have or shall be provided with a corresponding process control

transmitter to enable automatic comparison in DCS. Exceptions shall be subject to Owner approval, such as 2 out of 3 voting arrangement. In principle trip transmitters shall have the same range and accuracy as neighboring control transmitters, except of those for level. In all cases HH level trip transmitters and LL level trip transmitters in liquid/liquid interfaces shall have a narrower range than the control transmitter. The range for low flow protection (LL flow trip) shall be designed for the low delta-P during low flow rate and not for the higher delta-P during normal operation. For more detail on transmitters comparison,

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refer to the specification for DCS, S-000-1371-001.

3.1.23 All tagged field instrument equipment shall be fitted with a stainless steel label marked with tag number and service as minimum. Appendix-2 shows the typical label and font size.

3.2 CONNECTIONS 3.2.1 Instrument connection shall refer to S-000-1222-001 “Basic Engineering Design Data” and the

following table. Instrument Block Valve size and

type or Flange size of Instrument connection

Remarks

Connection to piping

Diff. Press. type flow instruments 1/2" gate valve (for 150#, 300#, 600#) 3/4” globe valve (for 900#, 1500#)

Thermowells Flange 1-1/2" Flange (Note. 3) Screwed N/A Press. Instruments and gauges 3/4" globe valve

Diaphragm type PG 1” Flange (Note. 2) PT 2” Flange PDT 3” Flange Connection to equipment

Thermowells Flange 1-1/2”, 2”, 3” Flange As per Equipment Data Sheets

(Note. 1) Press. Instruments and gauges 1" or 3/4” globe valve Level instruments External type

displ. and float 1-1/2" gate valve

Internal type displ. and float

4" Flange

Diff. press. type 1” or 3/4" gate valve Direct mount Diff.

Press type (Diaphragm type)

3” Flange

Ball float type level switch

1" gate valve

Note.1 Equipment Nozzle size: Minimum 1”. Nozzle size is to be as per Equipment Data Sheet. Note.2 PG connection for steam jacketed nozzle: 1-1/2” x 2” Flange Note.3 Thermowell connection for steam jacketed pipe: 3” Flange, for cement lined pipe: 4” Flange 3.2.2 Electrical entries to instrument shall be M20 x 1.5 or M25 x 1.5 female thread. 3.2.3 Pneumatic connections shall be 1/4 inch NPT. However larger size may be used, as required, e.g. for

high speed actuators or venting system on ESD equipment. 3.2.4 Process shutdown transmitters and switches shall be directly connected to the process lines or vessels.

3.3 SAFETY INSTRUMENT 3.3.1 Field switches and field panel mounted switches (including ESD push buttons) shall have hermetically

sealed contacts or gold plated contacts.

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3.3.2 All ESD alarms and shutdown switches shall be fail safe, i.e., switch contacts are closed at healthy plant condition and open to generate an alarm or shutdown. The status switch contacts are to be normally opened and closed to indicate status.

3.4 Unit and Scale

The units of measurement shall be Metric. Each engineering unit and measurement scale etc. shall be in accordance with instrument data sheet.

(1) Flow: Flowing Quantities

kg/h for mass m3/h for liquids kg/h, ton/h for steam

Standard Quantities Sm3/h for liquids (at 15°C and 1.013 bara) Nm3/h for vapor (at 0°C and 1.013 bara) (2) Level: % (percent of range)

(3) Pressure: barg for gauge pressure

bara for absolute pressure mbarg or mbara for low pressure bar or mbar for differential pressure (4) Temperature: °C (5) Other: Consult with Contractor

3.5 Accuracy

Unless otherwise stated, the accuracy of instruments shall be as follows: (1) Temperature gauge: +/-1.5 % of full scale (2) Electronic transmitter: +/-0.5 % of full scale (3) Pneumatic transmitter: +/- 1.5 % of full scale

3.6 Available utilities The available utilities with process conditions, such as plant air, steam and water etc., are described in S-000-1222-001 “Basic Engineering Design Data”.

4 CONTROL BUILDINGS 4.1 General

The instrument control and monitoring system (with DCS operator consoles and Man Machine Interface, MMI) will be installed in the following control buildings. (1) Main Control Building: MCB (2) Jetty Office (w/SS-31 & SIH-5): SIH-5 (3) Truck Loading Control Building (w/SS-23 & SIH-6): SIH-6

The instrument control and monitoring system (without DCS operator consoles and MMI) will be installed in the following buildings.

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(4) SIH-1 for Process Area-1 & 2: SIH-1 (5) SIH-2 for Process Area-3 & 4: SIH-2 (6) SIH-3 for Utility area: SIH-3 (7) Tankage Area Substation (w/SS-21 & SIH-4): SIH-4

The control system installed in these buildings will be linked with suitable communication network, i.e. extension of DCS redundant data highway, Ethernet or serial communication link etc.

The allocation of process units, utility units, off site units to these control buildings are described as follows. The detail shall be referred to D-000-1371-001 “DCS/ESD/FGS System Configuration”.

4.2 Main Control Building, SIH-1, SIH-2, SIH-3 and SIH-4

The main control building shall be used as the operational center for process units, utility units and off-site units. The equipment layout in main control building is shown in D-000-1378-201. The DCS, ESD, FGS, Plant Information Management System, other subsystem, communication system (e.g. CCTV, Paging, radio, telephone) etc., associated auxiliary panels/consoles, instrument power distribution panels and a UPS etc. will be installed in the main control building.

(1) The DCS and ESD system in MCB/SIH-1/SIH-2/SIH-3/SIH-4 will control and monitor the

following facilities. SIH-1 Unit 1100 Crude Distillation Unit (CDU) Unit 1200 CDU LPG Merox Process Unit (CDU LPG MEROX) Unit 1300 CDU Kerosene Merox Process Unit (KEROSENE MEROX) Unit 2000 Resid FCC Reactor Regeneration Section (RFCC RXRG) Unit 2100 Resid FCC Main Fractionation Section (RFCC MF) Unit 2200 Resid FCC Gas Concentration Section (RFCC GC) Unit 2300 Resid FCC Flue Gas Section (RFCC FLG) Unit 2600 Resid FCC LPG Merox Process Units (RFCC LPG Merox) Unit 2700 Propylene Recovery Unit (PRU) Unit 6500 Part of Waste Water Treatment SIH-2 Unit 3200 Distillate Unionfining Process Unit (DHDS) Unit 4000 TAME Selective Hydrogenation Process Unit (TSHP) Unit 4200 Gasoline HDS Unit (GHDS) Unit 3300 Hydrogen Generation Unit (HGU) Unit 3400 Sour Water Stripping Unit (SWS) Unit 3500 Amine Regeneration Unit (ARU) Unit 3600 Sulfur Recovery Unit Train 1 (SRU1) Unit 3650 Sulfur Recovery Unit Train 2 (SRU2) Unit 3700 Tail Gas Treating Unit (TGU) SIH-3 Unit 2800 Huels Selective Hydrogenation Process Unit (SHP) Unit 2900 Indirect Alkylation Unit (InAlk) Unit 4100 TAME Unit (TAME) Unit 5100 Power Plant, Electricity and Distribution System Unit 5200 Sea Water Intake Station Unit 5300 Water System Unit 5310 Cooling Water System Unit 5320 Sea Water Desalination Unit 5340 Portable and Service Water Unit 5400 Steam and Condensate System (STM) Unit 5500 Fuel Gas and Natural Gas Supply System (FG) Unit 5600 Instrument and Plant Air System (IA & PA) Unit 5700 Nitrogen System (N2) (by others) Unit 5800 Chemical Preparation and Injection Package Facilities Unit 5900 Flushing Oil System

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SIH-4 Unit 6100 Feedstock and Slop Tankage Unit 6200 Product and Component Tankage MCB Unit 6900 Flare System

(2) MCB/SIH-4 serves as the process control & monitoring, ESD and Fire & Gas system for the

above offsite facilities, Metering systems and other subsystems.

The DCS, ESD, F&G system, sub control systems (MOV, Tank Gauging System, etc.) and marshalling racks, associated panels and a UPS will be installed in this SIH. Note) The blending control for gasoline shall be configured by DCS or a dedicated computer. The further information will be provided in S-000-1371-004 “Product Blending Control System”.

(3) Weather monitoring instruments, i.e. wind speed and direction, ambient temperature and relative humidity will be installed at Main Control Building.

4.3 Jetty Office (SIH-5)

The marine control SIH is located at jetty and serve as control and monitoring ESD, and Fire & Gas system for Marine Loading Facilities (Unit 6400).

The DCS, ESD, Fire &Gas system, Loading /unloading arms control system, MOV system etc, marshalling racks, associated panels and a UPS will be installed. The DCS operator stations will be installed.

The equipment layout in marine control building is shown in D-000-1378-206.

4.4 Truck Loading Building (SIH-6)

The truck loading building SIH serves as the control & monitoring and FGS for following facilities, Truck Loading Automation System (TLAS) and other systems. Unit 3800 Sulfur Granulation Unit (SGU) Unit 6300 Truck Loading Facilities Unit 6500 Waste Water Treatment The DCS, FGS, Truck Loading Automation system, marshalling racks and a UPS etc. will be installed in this building. The DCS operator stations will be installed.

4.5 Instrument requirements for inside the control buildings 4.5.1 General

(1) Inside of the control buildings can be considered as safe area and under air-conditioned environment.

(2) The instruments installed in control buildings shall be mounted in auxiliary cabinets, racks or

on auxiliary consoles as required. Cabinet design and wiring colors shall be in accordance with S-000-1371-201 “Specification for Cabinet and Rack Design”.

(3) For DCS cabinets, operator consoles and ESD cabinets, manufacturer’s standard shall be

applied.

(4) Consideration shall be given for the uniformity in appearance for these cabinets, racks and consoles.

(5) All cabinets/racks etc. shall have bottom cable entries. Bottom plates shall be removable for

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cable installation. Steel bar(s) shall be provided to fix the external cables at the bottom. The mounting arrangements for cabinets shall take into account the sealing requirements for the extinguishing gas system below the raised floor.

(6) Maximum use should be made of plug and socket connections between the cabinets.

(7) The free access raised floor shall be provided for installation of cabinets and consoles.

(8) Redundant ventilation fans shall be installed where it is required for cabinets and racks. (9) To have uniformity the standard cabinet size for System cabinets, Auxiliary cabinets,

Marshalling racks, I/E Interface cabinets, Unit Control Panels, etc., S-000-1371-201 “Specification for Cabinet and Rack Design” shall be referred to.

4.5.2 Auxiliary Cabinets

The requirements for auxiliary cabinets shall be referred to S-000-1371-201 “Specification for Cabinet and Rack Design”.

4.5.3 Marshalling Racks

The requirements for marshalling racks shall be referred to S-000-1371-201 “Specification for Cabinet and Rack Design”.

(1) Lightning arrestors shall be provided for some instruments in off-site and utility area which are

not protected by any other means (i.e. not protected by structure etc.). Consideration shall be given to transient protection within some transmitters in these area, too.

4.5.4 Instrument and Electrical (I/E) interface cabinets

(1) MCC/DCS status signals, (running, available, current), shall be sent via single or redundant serial link. Operator start/stop signals shall be sent via redundant serial link. Start/stop signals for automatic take-over functionality of pumps/motors shall be hardwired to the interposing relays installed in the I/E interface cabinets. The shutdown signals from the ESD system shall be hardwired to the interposing relays installed in the I/E Interface cabinets. These cabinets will be installed in the associated substations.

5 CONTROL AND MONITORING SYSTEM 5.1 Distributed Control System (DCS) 5.1.1 General

The DCS shall provide the principal operating window for the plant. It shall contain microprocessor based fully redundant controllers with I/O devices, operator interface, data storage, printers and other auxiliary equipment.

Field devices will be hard wired to the DCS via marshalling racks. The DCS shall receive redundant power supply of 240Vac from a UPS with 30 minutes backup as minimum. The detailed requirements are described in S-000-1371-001 “Specification for DCS”.

5.1.2 Subsystem communication with DCS

The data transferred between DCS and Subsystems will be hardwired and/or serial communication link. In principal, the shutdown, interlock and control related signals shall be hardwired. The monitoring signals should be through serial communication.

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The detail shall be referred to S-000-1370-002, “Instrument and Control Philosophy”. 5.1.3 Blending control

The blending control will be configured by the DCS. The detailed specification of blending control system is described in S-000-1371-004.

5.1.4 Integrated Control and Information Management System (ICIMS)

ICIMS is described in S-000-1372-001. 5.1.5 Packaged unit control and monitoring

Packaged units will be controlled and monitored by a Unit Control Panel (UCP), supplied by the Vendor, or the DCS/ESD supplied by Contractor. The provision of primary control system of packaged units is described in S-000-1370-002 “Instrument and Control Philosophy”. Utilization of proprietary control and protection systems designed and manufactured by the Vendors, such as Gas/Steam Turbine Controller, Anti-Surge Controller (ASC), Vibration Monitoring System (VMS), and Burner Management System (BMS) will be defined in the relevant requisition and specification for the packaged unit.

5.2 ESD system 5.2.1 General

Shutdown logic and Depressurization shall be configured by fully redundant PLC basis system with TUV AK-6 certification as minimum. This system shall be independent from normal operational control system (i.e. DCS). The status monitoring for the shutdown system shall be through DCS via redundant serial links or connected with DCS data highway by redundant communication modules. Online ESD valve test function shall be provided. The detailed requirements are described in S-000-1371-005 “Specification for Online ESD Valve Testing”. The protective measures of ESD system shall include, but not necessarily be limited to, the following:

(1) Protection against over pressuring (2) Protection against over heating (3) Protection of uncontrolled chemical reaction (4) Protection against abnormal liquid levels (5) Activation of depressurization systems (6) Isolation/removal of liquid inventories contained in vessels (7) Prevention of flammable or toxic material atmospheric release (8) Prevention damage to equipment

5.2.2 The ESD system design shall be fail safe. 5.2.3 The ESD shall include a PC based sequence of event recorder (SER) with a printer for logging status

all input, output, override and resets. Operational override switches (OOS) and maintenance override switches (MOS) function will be configured by DCS software and be activated from DCS.

The detailed requirements are described in S-000-1371-002 “Specification for ESD”.

5.2.4 The ESD system shall receive the redundant power supply of 240VAC from a UPS with 30 minutes

back up as minimum. The output of shutdown circuit shall be 24 VDC. Outputs shall be “de-energized to trip”.

5.2.5 The shutdown of sub systems, which have dedicated PLC or relay based control and shutdown system,

will be performed by its own shutdown system. The ESD system shall give a hardwired shutdown command to these subsystems.

5.2.6 The ESD system shall shutdown motor control circuits in substations by hardwired signal via Instrument/ Electric (I/E) interface cabinets installed in associated substations.

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5.3 Fire and Gas system 5.3.1 General

Fire and Gas System (FGS) shall be provided for detection of fire and gas release. FGS for Process areas, (outside of buildings), shall be of the same make and type as the ESD System, redundant PLC's, TUV AK-6 certified. The system will be non-addressable. Location of system cabinets will be in MCB and SIHs. Separate systems for Gas detection and Fire detection are not required. The FGS shall perform fire fighting and control actions as well as indications for Fire/Gas Mimic panels (Plasma display). This system will provide audible and visual alarm indication in the Process areas. All Fire & Gas signals and alarms shall be sent over the redundant serial links to the DCS for primary DCS operator interface. For inside of buildings, a commonly used industrial type addressable fire detection system will be used. Building fire detection systems will provide the audible and visual fire alarms for the areas within the respective building. These systems will provide common fire alarms and common fault (etc.) alarms to the Fire & Gas System for Process areas (hardwired). Individual fire and gas alarms shall be displayed on the DCS. Common fire and gas alarms shall be provided on Mimic panels (Plasma display). Manual controls for FGS shall be provided on the operator console installed in Main control room (in MCB) and Jetty control room (in SIH-5). The operator console (in MCB) shall also include start push buttons and status indicators for the flesh water and sea water fire pumps. Monitoring PCs for individual fire and gas alarm shall be provided in the fire station and the control room (in MCB). The de-centralized battery concept shall be used, which provide backup power to FGS for minimum 4 hours. FGS outputs are contact closed to activate with line monitoring. FGS inputs for contacts are normally open, close to alarm with EOL resistors for line monitoring. The H2S horns and beacons shall have contact to close to activate. The H2S and LEL sensor shall have a horn and beacon located in the respective area. The further requirements are described in S-000-1370-002 “Instrument and Control System Philosophy” and S-000-1371-002 “Specification for ESD and FGS Systems”.

6 LOCAL CONTROL PANELS 6.1 Local panels shall be enclosed, self-supporting cubicle type panels, suitably gasketted to render them

dust and moisture proof. Sunshades/weather hoods shall be provided over local panels, which are exposed to direct sunshine or raining. Sunvisor over annunciater lamps shall be considered to prevent glare on the lamps. The minimum degree of protection is IP55 or NEMA 4X for outdoor mounted equipment. The local panel shall be made of anti-corrosion painted carbon steel or stainless steel. The anti corrosion paint shall be comply with the project painting specification.

6.2 Where the size of the cubicle would be disproportionate to the requirement, open panels with weather

protective cover should be considered, e.g. 3-side shelter, etc. 6.3 Instruments with direct process connections should be fitted in sections of the panel separate from

those containing electrical and pneumatic instruments.

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6.4 Electrical switchgear, (e.g. contactors), shall not be fitted in sections of the panel containing instrumentation and control equipment.

6.5 Each piece of panel mounted instrument shall be wired or tubed to suitable terminals mounted in the

panel. Separate terminal boxes shall be provided for each type of signal and power. Separate terminal boxes shall also be provided for ESD signals.

6.6 Where local panels contain relay and/or alarm logic system, consideration shall be given to the

climatic conditions. The relays in a local panel shall be hermetically sealed type or gold plated contact type.

6.7 All instruments mounted on the local panel shall have individual nameplates. Labels shall be made

of stainless steel and fitted by means of screws or adhesives. On front of panel, name plate labels shall identify instrument tag number and duty. On rear of panel, labels shall identify instrument tag number only. Abbreviation shall be in accordance with ISA RP 60.6.

6.8 Anti-condensation heaters controlled by thermostat or vortex tube cooler should be provided within

the panel unless the panel is located in an air conditioned environment or all equipment mounted in panel to be suitably tropicalized. External emergency lightning shall be provided on the local control panel for maintenance or operation, if required.

6.9 If a Local (Control) Panel contains lamps/indicators, a push-button for "lamp-test" shall be included in

the panel design. 7 TEMPERATURE INSTRUMENT 7.1 Temperature instrument shall be designed in accordance with API RP 551 and data sheets for each

temperature instrument with the following additions and options. 7.2 Transmission shall be by the application of direct head mounted type smart transmitters (4-20 mA). 7.3 The smart type transmitters shall be provided except for the bearing temperature and motor winding

temperature measurement for compressors and pumps. The bearing and winding temperature signals with RTD shall be directly connected to its related temperature monitors.

7.4 Unless otherwise stated, PT 100 ohm RTD element with 3 wires to IEC60751 shall be used where the

measuring temperature is 450 deg C and below. Type-K thermocouple shall be used where the temperature is above 450 deg C. Skin temperature shall be type-K.

7.5 For thermocouple of measuring temperature above 1100 deg C, or H2 service above 750 degC, care

shall be taken for the sheath material selection. 7.6 Multipoint temperature indication for reactors, etc., shall be achieved via the DCS. 7.7 Thermocouple and RTD circuits operating high temperature alarms shall have upscale element

burn-out. Those on low temperature alarms shall fail to down scale position. 7.8 Thermowell shall be designed in accordance with UOP standard drawing 6-105-4 “Thermowells” and

6-106-3 “Thermometer assembly”, except for the flange size.

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7.9 Karman vortex effect shall be calculated where it is required and thermowell shall have enough strength against it. Standard flanged thermowell size of 1-1/2 inch shall be used. At high fluid velocity, a shorten immersion length themowell or 2 inch thermowell design shall be used, and if required, a collared thermowell design may be applied. Thermowells shall be calculated for vibration and stress according to ASME Performance Test Code (PTC) 19.3.

7.10 Thermocouple head terminals shall be marked with positive and negative symbols.

The head shall be protected to IP55 or NEMA 4X as minimum.

7.11 The range of any temperature measuring instrument shall be the manufacturer’s narrowest standard span appropriate to the application. For local indicators, the following standard ranges are preferred: -20 to + 60 degC -0 to + 160 degC -0 to + 250 degC -0 to + 400 degC Scale ranges shall be selected such that the normal temperature shall be indicated within 30-70% of the range.

8 FLOW INSTRUMENT 8.1 General

The flow instrument shall be designed in accordance with API RP 551, UOP standard specification 6-18-1 “Flow Meters and Pressure Instruments” and data sheets for each flow instrument with following additions. The design and construction requirements for fiscal or commercial custody transfer flow metering systems are specified in S-000-1377-002 “Specification for Metering System”. The calculations for fiscal or commercial custody transfer flow meter shall follow the principles of API Manual of Petroleum Measurement Standards Chapter 2. The body of flow meters shall be suitably marked with the direction of flow. Inline or closed coupled (direct flanged) flow instruments are part of mechanical engineering, therefore material selection/examination, welding, treatments, testing, marking, certification, etc. shall apply with the project piping specifications and documents. To enable correct operation and service of flow device and flow meter, a typical installation requirements shall be prepared for flow meters. Any issue shall be highlighted as straight run length requirements per flow meter type and size, preferred transmitter positions, etc. Special delivery requirements as earthing rings, packing material, etc. should be included as well.

8.1.1 Bore calculation for orifice plates shall be in accordance with ISO 5167. For those items that fall outside of ISO 5167, the equations from ASME MFC-14M or the Flow Measurement Engineering Handbook (by Richard Miller) may be used. The design and construction requirement of orifice plates shall be in accordance with UOP standard specification 6-18-1 “Flow meters and Pressure instruments” and UOP standard drawing 6-111-4 “Orifice plates”, or ISO 5167.

8.1.2 The tapping for orifice plates shall be designed in accordance with API RP 550/551, unless otherwise

specified in the licenser data sheets, i.e. the orientation of the tapping on horizontal line shall be generally as follows:

Gas Service: Vertical (Top) or 45°Upward Liquid Service: Horizontal or 45°Downward Steam Service: Horizontal or 45°Upward

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Whenever a control function and a trip function are combined in one single primary flow measurement element, individual flow transmitters shall be installed (individual tapping connections on the orifice flange). The pressure lead tapping arrangement shall be referred to UOP standard drawings 6-115-6, 6-116-5, 6-139-3 and 6-140-3 “Orifice meter piping assemblies”.

8.1.3 The straight run length for orifices with flange taps and venturi tubes shall be in accordance with UOP

standard drawing 6-112-1 “Piping arrangements for Orifice plate installations” and 6-134-0 “Piping arrangements for Venturi installations”. Orifice with corner taps or D and D/2 taps, and flow nozzles (ISA 1932 nozzles or ASME long- radius nozzles) shall be in accordance with API RP 550 Part 1 or ISO 5167.

8.1.4 Orifice flange shall conform to ANSI/ASME B16.36. 8.1.5 Ultrasonic flow meters shall meet the following minimum requirements:

(1) Use an Ultrasonic transmit-time technique (2) Ultrasonic probes to be immersed in the fluid (3) Continuously measure velocity, volumetric and mass flow (4) Continuously determine instantaneous average molecular weight (5) Have a minimum of three assignable 4-20 mA analog outputs to indicate velocity, volumetric

flow, molecule weight, sound speed, or Mass Flow

Ultrasonic flow meters may be used for liquid and gas applications where there is the requirement for the flow measurement to present a minimum obstruction to the flow or for bi-directional flow measurement.

8.1.6 Vortex flow meter, inline type, may be considered as alternative where the its piping diameter is less

than 6 inch. Insertion type vortex flow meter may be used for large piping diameter. Vortex flow meter may be used for liquid, steam and gas where it has the benefits of high accuracy and high turndown ratio. However Vortex flow meter shall not be applied in wet steam and gas applications. In case of the Vortex flow meter is mounted in an inaccessible location, use of remote electronics shall be designed to avoid provision of platforms.

8.1.7 For mass-flow application, a volumetric flow meter together with pressure/temperature compensation may be considered. The flow compensation shall be calculated in the DCS. Coriolis type flow meters may also be used for the mass-flow measurement of gasses having sufficiently high pressure (density). Thermal dispersion mass-flow meters may be used for the measurement of air flows where high rangeability and large capacity is required.

8.1.8 Swirl flow meters may be used for the measurement of liquids and wet or dirty gasses where high rangeability is required or where limited upstream straight pipe is available. When no 24VDC loop-powered flow instrument is available for the application, an Electromagnetic flow meter may be used for all liquid and slurry applications, viscous and abrasive services, but also have sufficient levels of electrical conductivity.

8.1.9 Square root flow signals from the field shall be linearized in the flow transmitter and not in DCS, except where the square root signal is required in calculations or in control (e.g. antisurge control). Square root extraction outside field transmitter is subject to approval by Owner.

9 LEVEL INSTRUMENT 9.1 General

Level measurement shall be designed in accordance with API RP 551 and data sheets for each level instrument with the following additions and options.

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9.1.1 Where high corrosive, high toxic, or high flammable fluids are being measured, all impulse lines to

the transmitter should be provided with a restriction orifice. For safety during maintenance, a filling/flushing connector for purge should be installed on measurement piping lines of high toxic services to clean the piping line.

9.1.2 Differential pressure transmitter shall be used as a first choice for level instrument, wherever possible. 9.1.3 The tuning fork type level instrument should be considered for powder level and liquid level

measurement. 9.1.4 Restrictive magnetic level instrument should be considered for fluctuating density service and

interface measurement.

9.1.5 For applications where the level measurement is based on hydrostatic head and process fluid density variation is greater than +/- 10% occurs during normal operation and start-up, the reading at DCS shall be corrected for the density. The use of capacitance type of measurement shall be avoided for these cases.

9.2 Differential Pressure Type Level Instruments

9.2.1 When materials are liable to separate, solidify or deposit in impulse line, the lines should be purged or

trace heated, as appropriate. Alternatively direct mounting diaphragms may be used, and adequate mechanical protection for capillaries shall be provided. The effect of blockages or capillary failure on the integrity of process control and safety systems shall be assessed.

9.2.2 The appropriate seal liquid in the impulse line shall be specified in data sheets where it is required. 9.2.3 A dry or gas-purged reference leg should be used for applications where it is impractical to maintain a

filled reference leg, (e.g. in vacuum systems).

9.2.4 Where a continuous purge is employed, it shall be controlled by a constant-differential relay, so-called “purge set”. Tubing after the relay should be run in a continuous length to avoid leaks.

9.2.5 The transmitter should be mounted considering with maintenance accessibility via a platform or grade.

9.2.6 Care shall be taken for the accuracy affect due to thermal expansion of the filled fluid in capillary when using diaphragm seals for different pressure measurements. Seals and capillaries of remote seal transmitters shall be insulated to reduce ambient temperature effects, if necessary.

9.3 Displacement Type Level Instruments

The use of displacement type level instrument shall be minimized, and subject to approval by Owner.

9.3.1 Displacers should be mounted in external chambers. Chambers with Side-Bottom connections shall be provided on dirty fluids. On clean fluids, Side-Side connection may be used. Alternatives to the above arrangement are, but not in any special order:

- Top-Side - Top-Bottom The upper top connection should be avoided on condensing service as liquid droplets falling on the displacer could give erratic level measurements. The maximum allowable displacer length is 1524 mm. The standard range of displacer shall be of 356 mm, 610 mm, 813 mm, 1219 mm and 1524 mm.

9.3.2 Internal displacers may be used on vessels where an external arrangement is not feasible (e.g. sumps).

If necessary, a stilling well shall be provided to minimize the effect of level turbulence.

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9.3.3 Displacement type level instruments shall be glandless i.e. packing shall be avoided. 9.4 Float Type Level Instruments

9.4.1 Float type level switches should be mounted in external chambers. Internal floats may be used

within the restrictions detailed in 9.3.2. Float type switches shall not be used for storage tanks. The flanged chamber construction is preferred.

9.4.2 Float operated level switches shall be glandless.

9.4.3 The float shall be designed to withstand the test pressure of the chamber. 9.4.4 Integral stopper shall be provided to limit the float travel and shall be located as near to the float as

practical.

9.4.5 Ball float type switches will be directly mounted to vessel flange, accordingly the float arm and float shall be sized to pass through the nozzle.

9.5 Sonic and Radar devices 9.5.1 This technique should be considered for difficult applications on both solids and liquids at

atmospheric pressures.

9.5.2 The design should ensure that changes in the density of vapor space do not create unacceptable error. It shall be noted that sonic devices shall not be used where obstruction and high agitation can also affect the accuracy.

9.5.3 Use of the sonic level device should be considered, when the following service:

- On powder duty - Storage vessels - Effluent pit

9.6 Capacitance type

Capacitance type level instruments should be used in application where a small, lightweight probe may be mounted vertically through a top connection. The use of external chamber for process type measurement is more feasible than for the ultrasonic technique. Capacitance type level instrument shall not be used for viscous products.

9.7 Nuclear type level instruments

Typically used where no other form of level measurement is possible. Due to the dangers of radiation source strength containment, handling and installation must meet all national safety requirements.

9.8 Electromagnetic level instrument

Electromagnetic level instrument should be used where the fluctuating density or interface measurements.

10 PRESSURE INSTRUMENT

Pressure measurement shall be designed in accordance with API RP 551, UOP standard specification 6-18-1 “Flow Meters and Pressure Instruments” and data sheets for each pressure instrument with the

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following additions. 10.1 Pressure and Differential Pressure Transmitters 10.1.1 Transmitters should be used on pressure trip inputs.

10.1.2 Pressure instruments shall have overrange (for pressure) and underrange (for vacuum) protection to

prevent mechanical damage or 0 (zero) point shift in calibration. Where necessary, the overrange protection shall cover and exceed the relevant relieving pressure of safety relief valve. Transmitters shall be selected so that the steady normal operating pressure is below 75% of the maximum adjustable range.

10.1.3 All wetted components shall be 316 SS, unless otherwise specified differently in the data sheets.

10.1.4 The orientation and location of pressure tappings shall ensure:

(1) Ease of access for maintenance (2) Freedom from blockage and self-draining or venting properties (3) Avoidance of vibration (4) Avoidance of internal fitments, such as demister pads, stirrers and nozzle locations which

affect quality of measurement (5) Avoidance of long impulse lines

10.2 Pressure Gauges 10.2.1 The bourdon tube pressure gauge and vacuum gauge shall be designed in accordance with BS 1780

(1985) or BS EN 837-1, 2 and 3. 10.2.2 The installation and connection of pressure gauges shall be in accordance with UOP standard drawing

6-101-4 or API RP 551. 10.2.3 Pressure gauges shall generally be of bourdon tube type with nominal dial size of 100 mm.

10.2.4 Draft gauge may employ a quadrant edgewise indicator of suitable size.

10.2.5 Water gauge U-type manometers may be used for test purposes only.

10.2.6 Bellows or diaphragm sealed gauges may be used as necessary.

10.2.7 General

(1) Gauges will normally be of direct mount type with 1/2" NPT male bottom connections with

wrench flat. No thread adaptors shall be used.

(2) Flush mounting gauges shall be front flanged with clamp fixing, back connections with 1/4" NPT female thread with wrench flat for pneumatic receiver gauges, and 1/2" NPT for direct process connection.

(3) Bourdon tubes shall be welded to socket and tip and stress relieved as required. Materials of all wetted parts shall be type 316 stainless steel unless otherwise specified. Brass or other materials can be used for receiver gauges.

(4) Movement for all gauges shall be made of metals to withstand vibration or pulsation.

(5) Gauge cases shall be either

(a) Cast aluminum with weather proof screw ring type, or (b) Natural finished 316 stainless steel with bayonet type bezel ring and neoprene gasket. (c) Special plastic such as black phenol (it must be UV resistant )

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(6) Dials shall be white laminated steel with black numerals (for vacuum range, red numerals shall be employed) and markings.

(7) Gauge shall be provided with shatterproof glass and a blowout plug or a rupture hole at the

back of the case.

(8) Accuracy for the pressure gauges Bourdon type: 1% of FS between 10% - 90% of scale range 1.5% of F.S. over entire range Diaphragm/Bellows: 2% of FS over entire range Receiving gauges: 0.5% of FS between 10 - 90% of range

(9) Flanged pressure gauges with diaphragm seal shall be used where the materials are not suitable

for bourdon tube (e.g. high viscosity, slurry) The bottom section shall be removable for cleaning. The entire system above the diaphragm, including the element, shall be evacuated and entirely filled with an inert liquid. Flange rating shall comply with Piping Material Specification.

(10) Pressure elements shall be capable of withstanding intermittent overrange to 1.3 times the

maximum scale reading. When the pressure gauges can not withstand the maximum pressure expected during the operation, adequate protection for overpressure (gauge saver etc.) shall be provided.

(11) Pigtails or siphons shall be provided on condensable hot vapor service (higher than 100oC) and all steam service to prevent the heat from contacting the bourdon tube.

(12) Panel mounted gauges shall be a minimum diameter of 100 mm. Process connection shall be

as specified in (2) above. (13) All pressure gauges in pulsating services shall be furnished with a pulsation dampener.

10.3 Pressure Switches 10.3.1 Pressure switches shall be used for only where it is specified in data sheets and auxiliary service on

packaged unit. For fire detection applications and pump seals, pressure transmitters shall be used, and use of pressure switches shall be avoided.

10.3.2 All wetted parts shall be type 316 stainless steel as minimum unless otherwise specified. 10.3.3 All process connections shall be a minimum of 1/2 inch NPT. 10.3.4 Pressure switches shall have internal adjustment 10.3.5 Proof pressure shall cover the process design pressure. Special care shall be taken for the low

pressure detection. 10.3.6 Dead band shall be minimum. 10.3.7 Switches shall not be used on pressure less than 25 mbarg. 10.3.8 Switches shall not be used with any form of over range protection device. 10.3.9 Pressure switches shall be equipped with some form of indication to indicate locally on/off. _____

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11 VALVES

The requirements for control valves, shut-off valves and interlock valves shall be referred to S-000-1374-101 “General specification for control valves” and S-000-1374-201 “General specification for On-off valves”.

12 ANALYZER AND SAMPLING SYSTEM 12.1 General

Analyzer systems shall be designed in accordance with EEMUA 138 Design and Installation of on-line analyzer system. To reduce site work and to permit operational testing of the entire assembly before dispatch to site, analyzer shall be grouped and supplied in prefabricated analyzer house or racks, where possible. The detailed requirements are described in S-000-1375-001, Specification of Analyzers. Where electric heat trace is required for sample and return tubing, the pre-insulated tubing shall be used to maintain the required temperature. O2/NOx/SOx emission monitoring for stacks shall be as per specified on P&IDs.

13 INSTRUMENT CONSTRUCTION MATERIAL 13.1 Instrument tubing and fitting material

(1) Instrument pressure lead tubing shall be 1/2 inch O/D x 0.049 inch wall thickness stainless steel to ASTM A269 Grade TP316, cold drawn seamless and fully annealed. Tubing fittings shall be 1/2 inch O/D stainless steel ASTM A182 Grade F316, compression type, screwed NPT, high integrity, double ferrule, “Parker Hannifin” or equivalent with Owner’s approval. Stainless steel tubings and fittings may be used for line ratings 600lb and below, except for chloride containing services or where special materials are required.

(2) For normal service, instrument air tubing for transmission and control line shall be 1/4 inch to 1/2 inch OD x 0.035 inch minimum wall thickness, seamless copper to ANSI/ASTM B68 low phosphorus, deoxidised, soft annealed suitable for bending, PVC black copper sheath approx. 1.1 mm thickness.

- Tubings & Fittings shall be 1/4 inch to 1/2 inch OD brass compression type, screwed,

NPT, high integrity, double ferrule, “Parker Hannifin” or equivalent with Owner’s approval. Suitable for use with PVC covered copper tube i.e. Integral rubber O ring seal.

- Valves for local isolation and vent shall be 1/4 inch to 1/2 inch OD brass barstock ball valve, metal handle operated, screwed bonnet, 3000lb rating, ends threaded 1/2 inch NPT or ends complete with brass high integrity, double ferrule compression fittings .

13.2 Instrument piping

(1) Instrument air supply header shall be as follows:

- Pipe: 1/2 inch to 2 inch SCH80, Seamless carbon steel to ASTM A106

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Grade B or API 5L Grade B galvanized inside and outside, plain ends

- Pipe Nipple: 1/2 inch to 2 inch, SCH80, Seamless carbon steel to ASTM A106 Grade B or API 5L Grade B galvanized inside and outside, screwed ends

- Pipe fittings: 1/2 inch to 2 inch, 3000 lb, Galvanized, Forged carbon steel, Pipe fittings to ASTM A105 to BS 3799, screwed ends

- Unions: 1/2 inch to 2 inch, 3000 lb, Galvanized, Forged carbon steel to ASTM A105 Ground joint integral seat to BS 3799, screwed ends

- Plug: 1/2 inch to 2 inch, 3000 lb, Galvanized, Forged carbon steel to ASTM A105, Long solid round head type to BS3799, screwed ends.

- Swage nipples: 1/2inch to 2inch, SCH80, Galvanized, Forged carbon steel to BS3799

- Flanges: 1/2 inch to 2 inch, 150 lb RF, Galvanized, Forged carbon steel to ASTM A105, dimensions to ANSI/ASME B16.5

- Gasket & Bolts: As per piping specification

(2) Instrument piping For sour service, to NACE MR0175-02, instrument piping shall be provided resistance to Sulphide stress corrosion cracking and, where applicable, resistance to Hydrogen induced cracking. Other instrument piping requirement shall be in accordance with the project piping specification.

13.3 All support material, trays, ducts and stanchions, etc. shall be galvanized carbon steel.

Touch up paint shall be covered where required. 13.4 Instrument Cables 13.4.1 Instrument Cables shall be in accordance with BS 5308 Part 1 with Steel Wire Armored (SWA) for

outdoor cables and with non armored cables for indoor cables respectively. 13.4.2 The system cables between marshalling racks and system cabinets shall be the vendor’s standard

products. System cable installations shall be provided with adequate stress relief and not depended for support on their plug connectors. System cable entries to cabinets shall make due allowance for removal and insertion of system cables with their plugs fitted. Vendor to establish locking pin assignments of system cable plugs. All safeguarding connectors (ESD and FGS) shall have dedicated locking pin arrangements. Vendor shall develop a comprehensive test procedure in cooperation with the supplier to enable efficient and effective testing of the system cables with plugs.

13.4.3 All Junction Box will be generally installed on ground level for easy handling during construction

work and to minimize the risk of damage on multi core cables during construction and operation work.

13.4.4 Flame retardant cables shall be used for all under ground cables, indoor cables and above ground

cables which are installed in outside of fire protection area. Flame retardant cables shall be in accordance with IEC-60332-3-A. Within Fire-scenario Envelope, generally cables should not be laid. However, if it is impractical, under ground cables for ESD valves shall be with fire resistance insulation on the cable from ground to Junction Box. Above ground cables and branch cables for ESD valves (solenoid valves and positioners) shall be fire resistance cable between ESD valves (solenoid valves and positioner) and Junction Box. Fire resistance cables shall be in accordance with IEC-60331 Fire resistance characteristics of electric cables.

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13.4.5 Optical fiber cables shall be in accordance with S-000-1386-002 “Specification of Fiber Optical Cable and Communication Cables”.

13.4.6 Junction box

Junction box (J.B) shall be designed to meet suitable hazardous area classification and IP 55 as minimum. J.B material for outdoor use shall be 316 Stainless Steel. EEx“e” certified J.B shall be used. The minimum 20 % spare terminals shall be provided for incoming multi core cables. All J.Bs shall have a stainless steel name plate installed on its outside surface and an external earth bolt. The terminal shall be labeled in serial numeric number. The number of hubs for branch cables with corresponding to its multi core cable shall be provided. All spare hubs shall be plugged. The electrical hazardous certificate shall be provided for the junction boxes. Internal earth and screen rail shall be provided. Only bottom gland connection is acceptable. Breathers shall be provided to reduce internal condensation. Laminated terminal drawings shall be supplied in each junction box. Cable glands shall be provided for the cables terminated in the J.B.

13.4.7 All conductors of multicore cables shall be terminated at both field (junction box) and building side

(marshalling racks).

13.4.8 Solenoid valve circuits shall be used minimum wire size of 1.0 mm2. Voltage drop calculations shall be made to ensure adequate sizing of core diameters.

14 INSTALLATION OF INSTRUMENT Instrument installation shall be in accordance with UOP standard specification and drawings, API RP 551 and Typical Installation drawing and other applicable project documents. In addition to the above, the following requirements shall apply.

14.1 General 14.1.1 Care shall be taken to ensure that no passageways to equipment are obstructed.

Instrumentation requiring operator access should be mounted at a height of 1400 mm from grade or plat form. Direct connected devices such as level switches, displacers, thermowells, or tuning folk level instrument etc., have their elevation fixed by their respective process connections, in which case suitable access is to be provided.

14.1.2 Where field indicators are specified in P&IDs, the field indicator shall be located so as to be visible

from the associated control valve or final element, unless otherwise noted in other applicable documents.

14.1.3 Handrails shall not be used for mountings or supporting instruments. 14.1.4 Instrument field supports, J.B frames etc., shall be prepared and finished in accordance with detailed

drawings. Support brackets and supports of mild steel construction shall be galvanized. Galvanized thickness shall be 70 micrometer as minimum.

14.1.5 No instrument support shall be welded to a vessel, pipe or any other equipment containing process

fluids. The only exception to this shall be for instrument supports and brackets installed by the vessel fabricator at his work as part of the vessel dressing.

14.1.6 All instruments shall be mounted and supported so that it is free from vibration and misalignment. 14.1.7 Steam trace or electrical heat trace for pressure lead tubing, piping and analyzer sample tubing shall

be provided as shown in P&IDs. The electrical heat trace requirements shall be considered for analyzer sampling tubing where required.

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14.2 Instrument process piping and tubing 14.2.1 Maximum length of pressure lead tubings should be 6 meter. 14.2.2 All instruments requiring process measurement lines shall have an isolation valve. The first isolation

valve shall be under the piping discipline. 14.2.3 Stainless steel pipes or tubes shall not be located where, in the event of a fire, there is a possibility of

molten zinc falling onto the stainless steel from associated galvanized structures, zinc chromate paint, etc. This is necessary to eliminate the dangers caused by zinc embitterment of stainless steel.

14.2.4 Tubing shall not be supported from process lines except by acceptance of field engineer. 14.3 Instrument air piping 14.3.1 The location of instrument air headers and the take off points shall be shown on the instrument

location plan. 14.3.2 For sizing of the header line, the following size should be applied:

Up to 5 users: 1/2 inch nominal size – a user is considered to be 0.015 m3/ min. Up to 20 users: 1 inch Up to 50 users: 1 1/2 inch Up to 100 users: 2 inch Up to 200 users: 4 inch

14.3.3 All unused header distribution points shall be fitted with isolation valves and be suitably blanked. 14.3.4 All header distribution lines shall comply with the project piping specification. 14.3.5 All branch take off shall be from the top of header. 14.3.6 The drain legs shall be supplied at all lowest points of pocket including analyzer houses.

All isolation valves to instruments shall be anti-temper proof type, i.e. removable handle. 14.4 Instrument Cabling and wiring 14.4.1 Main instrument cables shall be run under ground where possible. 14.4.2 The cable entrance blocks, 6” PVC pipe, shall be used for cable entry to all control buildings (MCB

and SIHs). The 20% of spare cable entrance blocks shall be installed. 14.4.3 Multicore cables for main cables, (cables between Marshalling Rack and J.B), shall be sized to contain

min. 20% spare conductors at the issue of cable connection list as For Construction. For standard instrument signals (4-20 mA), multicore cables shall have an overall screen. For special signals such as frequency and vibration monitoring, multicore cables with individually screened pairs shall be installed.

14.4.4 Intrinsically safe circuits and non-intrinsically safe circuits shall not be contained within the same

cable, junction box and marshalling racks. I.S and non I.S cables may run together in the same tray or trench but shall be segregated into different bundles as far apart as possible.

14.4.5 Fire and Gas circuits shall be terminated in the dedicated junction box and marshaling racks. 14.4.6 Instrument analog signal cables shall be routed separately from electrical cables. The physical

separation of signals and power cables on parallel runs shall be as follows: Power wiring capacity Min. separation (mm) 240V & less 200

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415V 300 6.6 KV & 11 KV 600 33 KV and above 2000

The power cables installed under the control building floor shall be installed in the cable trays. The communication and data highway cables shall be installed in the dedicated cable tray separate from power cables. Optical fiber cables may be installed in the cable trays for both the power and signal/communication cables. Cable layout drawings shall be prepared showing the main cable runs under the control building/SIH floors. Main cables from field as well as system cables shall run in different bundles laid on the building floor.

14.4.7 It is allowed to run ESD, DCS, FGS multicore cables and other cables in shared cableways. 14.4.8 Instrument cables shall not run on the same trays as instrument piping and tubing. 14.4.9 Cables shall only be terminated in instruments, junction boxes or other approved equipment.

The intermediate cable joint shall be avoided in principal. However it shall be subject to Owner’s approval, if the cable joint is required.

14.4.10 Under ground cable installation

The multi core cables shall be installed in underground as principal. The underground cable shall be run in concrete hollow block trenches at paved area and in direct buried at unpaved area as per D-000-1378-001 “Instrument Typical Installation”. Instrument cables and electric power cables with voltage more than 240V AC shall not be installed in the same trench except for optical fiber cables. The separator shall be installed between instrument cables and power cables (240V AC) where both cables are installed in the same trench without enough distance (less than 200mm). The separator shall be earthed to plant earth. Optical fiber cables may be installed in the same trench as power cables with minimum distance of 10cm. DCS redundant data highway cables made of optical fiber shall be installed in the different trench (“A” and “B” DCS data highway cables shall have different cable routes through the plant). All removable protection tiles covering the direct buried trenches shall be color- coded as per D-000-1378-001 “Instrument Typical Installation”. Crossing beneath roads shall be by means of ducts encased in concrete. The route of all main trenches shall be shown in detailed drawing based on the typical cross section of cable trench drawing.

14.4.11 Above ground cable installation

(1) All branch cables and multi-core cables, where necessary, shall be installed in the ladder rack and cable trays. The ladder rack shall be used for large routes and cable trays for small (below app. 200-mm width).

(2) All supports and joint fittings shall be heavy duty, mild steel galvanized. Unprotected

supports shall be painted prior to cable installation. Supports for ladder rack and tray shall be fixed to suitable structure steel and concrete, before the application of any fireproofing. Welding is preferred method of fixing to structure steel. Galvanizing shall be repaired after welding. Supports shall not be welded to vessels or pipework.

(3) Cable ladder cover shall be installed where they are installed on the top of multiple layers cable

ladders, vertically installed and exposed by direct sun shine. The covers will be clamped on the tray or ladder for cable maintenance.

(4) Individual cable runs near to the final termination point, such as individual field instrument

shall be run in galvanized mild steel angle or proprietary channel section. Conduit shall not be used.

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(5) Above ground cables shall be fixed using stainless steel tie band, pre-formed saddles or stainless steel strapping. Cables should be fixed at approximately 250mm interval in vertical runs and 500-mm intervals on horizontal runs.

(6) Cables connected to instruments shall be installed with a loop of cable to provide sufficient

slack for remaking the cable connection if the instrument is removed and to allow for removing the instrument without electrical disconnection.

14.4.12 Cable Gland

(1) All cables in the field shall be glanded. Cable glands shall comply with BS6121 part1.

(2) Cable glands are not normally required for cables in control buildings.

(3) The following general requirements are applicable to all gland installations:

- All glands shall comply with its electronic hazardous protection and maintain the IP rating of the associated equipment.

- The gland tread shall match that of associated equipment. - The use of thread adapters shall be minimized.

14.4.13 Cable, J.B and Wire marking

Every instrument cable and junction box is allocated a number. All these number shall be shown on the detailed drawings and are marked on cables, wires and junction boxes in accordance with the typical label written in the typical installation drawings.

14.4.14 Fireproofing

Fire proofing shall be in accordance with S-000-13B0-001 “General Specification for Fireproofing”.

15 EARTHING SYSTEM

The earthing of the system and I/O connections shall be in accordance with the Electro Magnetic Compatibility (EMC) directives. Earthing, Lightning and EMC installation requirements shall comply with the IEC standards (e.g. IEC 61000) and local national (authority) standards/practices.

15.1 Detailed Instrument earthing philosophy shall be referred to D-000-1370-001 and the following

general principal:

(1) All equipment containing a signal or power supply shall be earthed for personal safety reasons and for minimize electrical interference. This includes instruments, enclosures, cables, cable trays, and conduits.

(2) Cable screens shall be electrically continuous through the cable run and shall be earthed at one

point only. This point is normally the panel reference bar or the panel or cabinet which the cable is connected to. It shall be shown in the detailed instrument earth drawing and each loop drawing.

(3) Steel wire armor shall be electrically continuous through the cable run and shall be earthed

normally at the control building and junction box.

(4) The plant earth, instrument system earth and I.S earth bars shall be provided in rack rooms (MCB and SIHs).

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16 DOCUMENTATION 16.1 General

The following is a special note for instrumentation. All documents shall be submitted in accordance with the specification S-000-1140-104 “Document Requiring Owner’s Review”.

16.1.1 Instrument design tool will be INtools, AutoCAD, MS Excel, Access, etc. 16.1.2 Any application software is to be provided to Owner. 16.1.3 All drawings are to be developed individually for each plant except typical installation drawings;

common drawings are not acceptable. 16.1.4 Documentation and data base list are to be checked, completed with all engineering information added,

revised as needed and finalized. 16.1.5 At project completion, all key drawings including vendor issued drawings are to as built in accordance

with S-000-1140-104. These key documents may be submitted by agreed electronic media written by agreed software e.g. MS Word, Excel, Access, Auto CAD etc.

16.1.6 Contractor is to verify all logic on the Cause and Effect table, and reformatted to use the standard

table form. 16.1.7 In general, all instrumentation sizing, selection, installation and wiring are to be in accordance with

Contractor’s furnished design practices, engineering standard, material system specifications, and industry standards.

17 SPARE PARTS

Refer to S-000-1224-701 “Spare Parts Philosophy”.

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18 APPENDIX – 1 LIST OF REFERENCED DOCUMENTS The design, construction and installation of the control system and instrumentation shall, as minimum, comply with the following industrial code and standard as applicable. All works shall be performed in accordance with the latest edition as of May 19, 2003 unless otherwise specified. 1. ANSI, ANSI/ASME, ANSI/FCI, ANSI/MC or ASME 1.1 ASME Boiler and Pressure Vessel Code Section I : Power Boilers 1.2 ASME Boiler and Pressure Vessel Code Section VIII Div.1 : Pressure Vessels 1.3 ANSI/ASME B1.20.1 - 1983 : Pipe Threads, General Purpose (Inch) 1.4 ANSI/ASME B16.5 a- 1998 : Pipe Flanges and Flanged Fittings 1.5 ANSI/ASME B16.34a - 1996 : Valves-Flanged, Threaded and Welding End 1.6 ANSI/ ASME B16.36 : Orifice flanges 1.6 ASME B31.3 - 2002 : Process Piping 1.7 ANSI B46.1 - 2002 : Surface Texture 1.8 ANSI/FCI70-2 - 1991 : Control Valve Seat Leakage 1.9 ANSI/MC 96.1 - 1982 : Temperature Measurement Thermocouples 1.10 ASME MFC - 3M : Measurement of Fluid Flow in Pipes Using Orifice, Nozzle &

Venturi 1.11 ASME MFC 14M : Measurement of Fluid Flow Using Small Bore Precision Orifice Meters 1.12 ASME PTC 19.3 : Temperature Measurement 2. API 2.1 RP-551 - 1993 : Process measurement Instrumentation 2.2 RP-554 : Process Instrument and Control 2.3 RP-555 : Process Analyzer 2.4 API Manual : Petroleum measurement standard 2.5 API 670 : Non-contacting vibration and axial position monitoring system Note: RP 550 is now obsolete, the requirements contained therein are to be complied with , except where superseded by the API RP 551, 554 and 555. 3. ASTM 3.1 A269 : Specification for Seamless and Welded Austenitic Stainless Steel Tubing for General Service 3.2 A276 : Specification for Stainless and Heat Resisting Steel Bars and Shapes 3.3 D1250-80 (1990) : Guide for Petroleum Measurement Tables 4. BS 4.1 BS 1904 : Industrial Platinum Resistance Thermometer Elements 4.2 BS 3463 : Observation and Gauge Glasses for Pressure Vessels. 4.3 BS 2765 - 1981 : Specification for Dimensions of Temperature Detecting Elements and Corresponding Pockets 4.4 BS 5345 Part7 : Installation and maintenance requirements for electrical apparatus with type of protection N 4.5 BS 5308 Part 1 : Instrumentation Cables 4.6 BS 5351 : Steel ball valves for petroleum, petrochemical and allied industries 5. CENELEC

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5.1 EN50014 - 1977 : Electrical apparatus for potentially explosive atmosphere. General requirement 5.2 EN50016 - 1977 : Pressurized apparatus P 5.2 EN50018 - 1977 : Flameproof enclosure d 5.2 EN50019 - 1977 : Increased safety e 5.3 EN50020 - 1977 : Intrinsic safety i 6. IEC 6.1 IEC 60079-0 : Electrical apparatus for explosive gas atmospheres - Part 0 : General 6.2 IEC 60079-1 : Electrical apparatus for explosive gas atmospheres - Part 1 : Flameproof enclosure ‘d’ 6.3 IEC 60079-2 : Electrical apparatus for explosive gas atmospheres - Part 2 : Pressurized enclosures ‘p’ 6.4 IEC 60079-7 : Electrical apparatus for explosive gas atmospheres - Part 7 : Increased safety “e” 6.5 IEC 60079-8 : Classification of maximum surface temperature 6.6 IEC 60079-11 : Electrical apparatus for explosive gas atmospheres - Part 11 : Intrinsic safety ‘i’ 6.7 IEC 60079-14 : Electrical apparatus for explosive gas atmospheres - Part 14 : Electrical Installation of hazardous areas 6.8 IEC 60331-21 : Fire resisting characteristics of electrical cables 6.9 IEC 60332 : Test on electrical cables under fire conditions 6.10 IEC 60529 : Degree of protection provided by enclosure (IP Code) 6.11 IEC 60534-8-3 : Industrial process control valves, noise considerations, control valve aerodynamic noise prediction method. 6.12 IEC 60534-8-4 : Industrial process control valves, noise considerations, prediction of noise generated by hydrodynamic flow. 6.11 IEC 61000-4-3 : Electromagnetic compatibility (EMC) : Testing and measurement techniques 6.12 IEC 61511-1/2/3 : Functional safety of Safety instrument system for the process industry sector 6.12 IEC 60751 - 1983 : Industrial platinum resistance thermometer sensors 7. NEC 7.1 NEC : Articles 100,500,501,504 ,505 7.2 NEC 725 : Cable installation on cable tray 8. ISA 8.1 ISA 5.1 : Instrument symbol and specification 8.2 ISA 5.2 : Binary logic diagram for process operation 8.3 ISA 5.3 : Graphic symbol for distributed control/ shared display instrument logic and computer system 8.4 ISA 5.4 : Instrument loop diagram 8.5 ISA 12.4 : Instrument purging for reducing of hazardous area classification 8.6 ISA 18.1 : Annunciator sequences and Specifications. 8.7 ISA 20 : Specification forms for process measurement and control

instrument 8.8 ISA 51.1 : Process instrumentation terminology 8.9 ISA RP 60.6 : nameplates , label and tags for control centers 8.10 ISA 75.01 : Control valve sizing equation 8.11 ISA 75.05 : Control valve terminology 8.12 ISA 75.13 : Method of evaluating the performance of positioners with analog input signals and pneumatic output. 8.13 ISA 75.17 : Control valve aerodynamic noise prediction

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8.14 ISA 75.25 : Control valve dynamic testing 9. ISO 9.1 ISO 5167-2003 : Measurement of fluid flow by means of pressure differential devices 9.2 ISO 5168 : Measurement of fluid flow –Evaluation of Uncertainties 9.3 ISO 9000-1 : Quality management and quality assurance 10. JIS 10.1 C0903-1983 : Electrical apparatus for explosive atmospheres in general industry 11. NEMA 11.1 NEMA-ICS-6 : Enclosure for industrial control and system 12. TIIS 12.1 RIIS-TR-85-1 : Recommended practice for explosion-protected electrical installation in general industries 13. EEMUA 13.1 EEMUA 138 : Design and installation of on-line analyzer systems 13.2 EEMUA 133 : Armoured cable protected against solvent penetrations and corrosive attack 14. CCITT Recommendation G651 and G652/G703 for fiber optic 15. NFPA Applicable code and standard shall refer to S-000-13B0-001, General Specification for Fireproofing. 16. NACE-MR0175-2002 Sulfide stress cracking resistance metallic materials for oilfield equipment

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19 APPENDIX – 2 NAME PLATE

11-FT-012ZZZZZYYYYYXXXXXRRRRR

AAAAABBBBBCCCCCDDDDD

108

120

6

30

1.0

Φ5

Engraving : Maximum 3 lines, characters to be 5mm hight, black color.First line to specify instrument tag number only.Second and third lines shall be service descliption (Total max40 characters).

Material : Stainless Steel

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1 Orpic Definitions and RFQ/PO Instructions to Bidders for RFQ, PO & PC

1.1 Orpic is the brand name of Oman Oil Refineries and Petroleum Industries Company SAOC (Commercial Registration Number 1113003). OrpicAromatics is the brand name of Aromatics Oman LLC (Commercial Registration Number 1798189). Orpic Refineries is the brand name of OrpicRefineries LLC (Commercial Registration Number 1134221). Orpic Plastics is the brand name of Orpic Plastics LLC (Commercial Registration Number1218747). The Orpic brand represents the integrated management of these operating companies and this RFQ may be issued by Orpic for and onbehalf of any or all of these operating companies, together with Orpic#s and their respective co-ventures, affiliates, officers, employees and agents,collectively the #Orpic Group".

1.2 Bidder is Company responding to this RFQ with a Quotation. Bidder is requested to acknowledge receipt of this RFQ by return email to theProcurement Officer who issued the RFQ.

1.3 Seller/Contractor. For the purposes of this document Seller and Contractor shall mean the party that is contracted to Orpic.

1.4 Purchase Order, Service Order, Contract and Agreement shall mean the same.

1.5 Scope of Supply and/or Services shall be attached separately (if applicable)

1.6 Party means either of Orpic or the Seller/Contractor and Parties means both of them together.

1.7 Price means the price as more particularly described in the Service Order to be paid by Orpic to the Contractor.

1.8 Registration Requirements.Unless otherwise agreed by Orpic Bidder must be registered with Orpic & Joint Supplier Registration System (JSRS) as an approved Seller for thematerials / services to be offered by their Quotation. If Bidder is not registered, the registration forms are available from Orpic Procurement &Contracting Dept, PP Building, Sohar. Bidders may contact the Procurement Officer who issued the RFQ to arrange to collect the forms. These formsmust be completed and submitted by Bidder not less than 10 days before the Submission Date of this RFQ. Bidders must sign Orpic's ConfidentialityDeclaration or Non-Disclosure Agreement, (NDA) as directed by the Procurement Officer and submit with the Seller registration forms or the Quotation.

1.9 Quotation. Bidder shall submit its Quotation by completing the necessary sections of the enclosed Orpic RFQ only. Bidder may only indicatedeviations relating to the subject matter of the RFQ by clearly indicating where the Quotation differs from the RFQ requirements and any proposedamendments. However Orpic is not obliged to accept any deviations. Bidder shall provide the complete breakdown of pricing required. The Quotationand any resultant Purchase Order/Service Order shall be governed by Orpic General Conditions for Purchase and Minor Services, attached below, andOrpic may not accept any changes to these General Conditions of the Purchase Order for Purchase and Minor Services. Bidder must submit two signedcopies of the Purchase Order with all sections duly completed. Submitting a Quotation in any other format may result in Bidder's Quotation beingrejected at Orpic's sole discretion.

1.10 Acceptance. Acceptance by Orpic will be confirmed by the issuance of a Purchase Order/Service Order within the Quotation validity period whichshall be binding. One countersigned copy of the Purchase Order/Service Order may be returned to the Bidder.

1.11 Clarifications. If Bidder requires any further information or clarification regarding this RFQ then a request for clarification shall be sent in writing tothe Procurement Officer who issued the RFQ and whose name and email is stated above.

1.12 Regrets. If Bidder is not in a position to submit a Quotation, Bidder is requested to confirm by email to the Procurement mail.

1.13 Advance Payment Bond. If Orpic agrees to an Advance Payment then it will be on condition that the successful Bidder submits an AdvancePayment Bond in accordance with the General Conditions Applicable for Procurement of Goods and Services and in the exact format detailed inAppendix 3. If an Advance Payment for supply of Goods or Services is agreed then an Advance Payment Bond and or Bank Guarantee from aregistered bank in the Sultanate of Oman, acceptable to Orpic, in an amount equal to the Advance Payment shall be submitted by the Seller/Contractorto Orpic. Submission of any Advance Payment Bond or Bank Guarantee from a registered bank outside of the Sultanate of Oman shall be pre-approvedby Orpic prior to submission.

1.14 Submission of Quotation. The date, method and location for submitting the Quotation will be indicated on the front page of the RFQ. Any Quotationreceived after this date & time will be rejected or accepted at Orpic#s sole discretion.

1.15 No Obligation. Orpic is not obliged to accept the lowest priced Quotation or any Quotation. Orpic is not obliged to provide any reasons for rejectingany Quotation. Orpic may, at its sole discretion, reduce or increase the quantity ordered or split orders between Bidders.

1.16 Extension. Bidder must request any extension of time not less than 48 hours before the Submission Date. Orpic may or may not agree to award anextension at its sole discretion.

1.17 Validity. Bidder's Quotation shall be valid for not less than ninety (90) days from the Submission Date.

1.18 Tax means any and all net income, gross income, gross receipts, sales, use ad volorem, transfer, franchise, net worth, profits, license, lease,service, service use, withholding, payroll, employment, excise, severance, stamp, occupation, premium, property, real property taxes and fees, customs,duties or other taxes, fees, assesments levies, charges or other impositions of any kind whatsover or obligatory charge of like or equivalent nature,together with any interest thereof and any and all penalties, additions to tax, or additional amounts with respect thereto, imposed by or on behalf of anyGovernmental Authority.

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2. General Conditions Applicable for Procurement of Goods and Services

2.1 Payment. The Price of the Goods and/or Services shall be the amount set out in the Purchase/Service Order. The Price is the total amount due tobe paid by Orpic to the Seller in respect of satisfactory performance by the Seller/Contractor of its obligations under this Purchase/Service Order. ThePrice is inclusive of amounts in respect of any applicable taxes duties or similar charges and for Goods includes the costs of packaging, insurance andcarriage of the Goods. No extra charges shall be effective unless agreed in writing and signed by Orpic. All costs associated with preparation ofSeller's/Contractor#s bid, quotation, development of offer or related to this Purchase/Service Order are for Seller's/Contactor#s account. Any legalizationcosts for packaging and documentation including Material Test Certificates or Conformance Certificates are for Seller's account. The Seller may invoiceOrpic for the Goods on or at any time after the completion of delivery. The Contractor may invoice Orpic for the Services performed on or at any timeafter Completion or as set out in the Scope of Services. Seller shall submit following documents for payment: Invoice; PO / PC copy; and Proof ofdelivery / service completion report.

2.2 Orpic shall pay undisputed and correctly rendered invoices from the Seller/Contractor within thirty (30) days of the later of either receipt of theinvoice or Completion of the Services or to acceptance of the Goods, as the case may be. Payment shall be made to the Contractor's bank account. Inthe event of a dispute over all part of an invoice, Orpic shall pay the undisputed part in accordance with this Clause and the Parties shall discuss in goodfaith to resolve the disputed part. Orpic may, without limiting any other rights or remedies it may have, set off any amount owed to it by theSeller/Contractor against any amounts payable by it to the Seller/Contractor under this Purchase/Service Order.

2.3 Audit Rights. Orpic shall have the right, to inspect and audit any of Seller's/Contractor#s records, including data stored on computers, books,personnel records, accounts, correspondence, memoranda, receipts, vouchers and other papers of every kind in connection with this Purchase/ServiceOrder and/or Goods and all transactions related thereto as may be necessary in the opinion of Orpic to verify that the requirements of thisPurchase/Service Order are being met and shall have access to all information relating to the rates and prices as may reasonably be required to verifypayments made to or by Seller/Contractor under or pursuant to this Purchase/Service Order. Such inspections and audits may be carried out by Orpic inrespect of this Purchase/Service Order at any time until expiry of twenty four (24) months from the end of the calendar year in which thisPurchase/Service Order is terminated or completed. Orpic shall use all reasonable endeavours to conduct any such inspections and audits in a mannerwhich shall result in a minimum of inconvenience to Seller/Contractor.

2.4 Liability & Indemnity. The Seller/Contractor shall indemnify Orpic against all liabilities, costs, expenses, damages and losses (including but notlimited to any direct losses and all interest, penalties and legal and other professional costs and expenses) suffered or incurred by Orpic arising out of orin connection with: a) any claim made against Orpic for actual or alleged infringement of a third party's IP Rights arising out of, or in connection with, thesupply or use of the Goods; b) any claim made against Orpic by a third party arising out of, or in connection with, the supply of the Goods, to the extentthat such claim arises out of the breach, negligent performance or failure or delay in performance of this Purchase/Service Order by theSeller/Contractor, its employees, agents or subcontractors; and c) any claim made against Orpic by a third party for death, personal injury or damage toproperty arising out of, or in connection with, defective Goods, to the extent that the defect in the Goods is attributable to the acts or omissions of theSeller/Contractor or Manufacturer, its employees, agents or subcontractors.

The Seller/Contractor shall indemnify Orpic from and against all claims ,liabilities or losses arising by reason of the following if connected with theperformance of this Purchase/Service Order: a) all injury to ,death, or illness of persons in the Supplier Group; and b) all damage to or loss of property ofthe Supplier Group, even if caused by negligence or fault of the Orpic Group or any other person. The Seller/Contractor shall indemnify Orpic from andagainst all claims, liabilities or losses arising by reason of the following if connected with the performance of this Contract: a) all injury to, death, orillness of third parties; and b) all damage to or loss of third parties' property, to the extent caused by the negligence or fault of the Supplier Group, even ifcontributed to by the joint or concurrent negligence or fault of the Orpic Group or any other person; provided that, in the event of joint or concurrentnegligence or fault of the Supplier Group and the Orpic Group, the Supplier's indemnification obligation shall be limited to the Supplier Group'sproportionate share of such negligence or fault.

Orpic shall indemnify the Seller/Contractor from and against all claims, liabilities or losses arising by reason of the following if connected with theperformance of this Purchase/Service Order: a) loss of or damage to Orpic's property, except that nothing in this clause will in any way limitSeller/Contractor's obligations to remedy defects, whether owned, leased or otherwise obtained under arrangements with financial institutions arisingfrom or related to the performance of this Purchase/Service Order; b) Personal injury including death or disease to any person who is an employee ofOrpic arising from or relating to the performance of this Purchase/Service Order; c) subject to any other express provisions of this Purchase/ServiceOrder, personal injury including death or disease or loss of or damage to the property of any third party to the extent that any such injury, loss or damageis caused by Orpic's negligence or breach of duty (whether statutory or otherwise).

2.5 Consequential Loss shall mean: Consequential loss; and/or loss of production, loss of product, loss of use, loss of business and businessinterruption and loss of revenue, profit or anticipated profit whether direct or indirect arising from or related to the performance of this Purchase/ServiceOrder, whether or not such losses were foreseeable at the time of entering into this Purchase/Service Order. Except to the extent of any agreedremedies expressly provided for in this Agreement but notwithstanding anything else to the contrary in this Agreement, neither Orpic nor Contractor shallbe liable to the other for any Consequential Loss which may be suffered by the other in connection with this Agreement.

2.6 Applicable Law and Dispute Resolution. The laws of the Sultanate of Oman shall govern the construction, validity and performance of thisPurchase/Service Order. Unless otherwise agreed, any dispute arising out of or in connection with this Purchase/Service Order which cannot beresolved to the mutual satisfaction of the Parties then the Parties hereto agree to submit to the jurisdiction of the courts of Oman to resolve any matter indispute.

2.7 Force Majeure. Except as may be specifically otherwise provided in this Purchase/Service Order, neither Party shall be liable for delays inperformance or for non-performance directly occasioned or caused by Force Majeure. Force Majeure means Acts of God, war (declared andundeclared), riots, civil commotion, revolution, hostilities, epidemics, blockades, nuclear hazards, extreme weather conditions, acts of any Governmentcausing a political embargo or other political restraint adversely affecting the freedom to transact business with or in the Sultanate of Oman and anyother similar cause or of equivalent force occurring within the Sultanate of Oman which is beyond the control of the Parties, unavoidable and whichcould not reasonably be foreseen and which renders impossible the fulfilment of a particular term of this Purchase/Service Order. Strikes, lockouts or

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differences with workers which are limited to Seller/Contractor's personnel or those of Seller/Contractor's sub-Seller/Contractors and inability of eitherParty to secure funds shall not be regarded as Force Majeure.

2.8 Assignment and Sub-Contracting. Seller/Contractor may not assign, subcontract or transfer any part of this Purchase/Service Order or theobligations of Seller/Contractor under or related to this Purchase/Service Order without the prior written approval of Orpic. Approval by Orpic of asub-contractor shall not relieve Seller/Contractor from its responsibility for performance of the part of this Purchase/Service Order that is subcontracted.

2.9 Confidential Information. All information obtained by Seller/Contractor for or in connection with this Purchase/Service Order and Seller/Contractor'ssupply of the Goods/Services shall be considered confidential and shall not be used by Seller/Contractor other than for the purposes of supplying theGoods/Services, or divulged by Seller/Contractor, its servants or agents to any person, firm or corporation other than Orpic#s designated representative.The foregoing restrictions shall not apply to any information disclosed by Orpic to Seller/Contractor which: a) At the time of disclosure is in the publicdomain, or b) After disclosure becomes part of the public domain, or c) Seller/Contractor can show was rightfully in its possession at the time ofdisclosure without limitation or restriction as to use or disclosure, and was not acquired directly or indirectly from Orpic, or d) Seller/Contractor rightfullyreceives from any third party who did not receive such information directly or indirectly from Orpic with limitation or restriction as to use or disclosure.

2.10 Termination. In the event of Seller/Contractor's failure to perform or other breach of this Purchase/Service Order, Orpic shall have the right toterminate this Purchase/Service Order forthwith without being first obliged to seek any remedy by Seller/Contractor. Termination under this clause shallbe at no extra cost to Orpic. Orpic reserves the right to terminate this Purchase/Service Order at any time by giving Seller/Contractor written notificationspecifying the date of termination. Orpic shall pay Seller/Contractor for Goods satisfactorily delivered and accepted and Services satisfactorilyperformed and accepted up to the date of termination and other reasonable associated direct costs incurred in complying with Orpic's instructions. In noevent shall Seller/Contractor be entitled to any prospective profits or any damages resulting from such termination.

2.11 Costs. Each Party shall pay its own costs incurred in connection with the negotiation, preparation, execution and performance of this agreementand any documents referred to in it.

2.12 Variation. No variation of this agreement shall be effective unless it is in writing and signed by the Parties (or their authorised representatives).

2.13 Waiver. No failure or delay by a Party to exercise any right or remedy provided under this agreement or by law shall constitute a waiver of that orany other right or remedy, nor shall it prevent or restrict the further exercise of that or any other right or remedy. No single or partial exercise of suchright or remedy shall prevent or restrict the further exercise of that or any other right or remedy.

2.14 Language. This Purchase/Service Order is drafted in the English language. If this Purchase/Service Order is translated into any other language, theEnglish language version shall prevail.

2.15 Notices. A notice given to a Party under or in connection with this Purchase/Service Order shall be in writing and sent to the Party at the address orto the fax number given in this Purchase/Service Order or as otherwise notified in writing to the other Party. Any notice given under or in connectionwith this Purchase/Service Order shall be in the English language. All other documents provided under or in connection with this agreement shall be inthe English language, or accompanied by a certified English translation. If such document is translated into any other language, the English languageversion shall prevail unless the document is a constitutional, statutory or other official document.

2.16 Anti-Bribery and Corruption. A Person shall be defined as a third party including, but not limited to: government officials (including directors,officers and employees of government owned and/or controlled entities); any director, officer or employee of Orpic or its subsidiaries, or their relatives;any candidate for public office; or any agents or intermediaries of any of the foregoing. The Seller/Contractor agrees and confirms that, in connectionwith the award or execution of the Purchase/Service Order, and any and all transactions contemplated by this Purchase/Service Order, it will fullycomply with all applicable legislation relating to anti-bribery and anti-corruption, including, but not limited to, Royal Decrees (including: Royal Decree 7 of1974 promulgating the Oman Penal Code; Royal Decree 112 of 2011 promulgating the Law of the Protection of Public Funds and Avoidance ofConflicts; and Royal Decree 64 of 2013 ratifying the United Nations Convention Against Corruption), regulations, ministerial directions and orders of theSultanate of Oman. The Seller/Contractor agrees and confirms that it, and each of its affiliates, and their respective directors, officers, employees,agents and any other person acting on its, or their, behalf has not, and will not, directly or indirectly, make, offer, authorise, promise, mediate or becomeany way involved in a payment or transfer of anything in value, including the provision of any advantage or any showing or providing favour or disfavourto anybody, or any service, gift, entertainment, promise, reward, rebate, discount, contribution, commission, incentive, inducement, to any Person whichis intended to be, or could reasonably be construed or perceived as being, an inducement or reward for that Person doing or not doing any act, orpromising to do or not to do any act. The Seller/Contractor agrees and confirms that, in connection with the award or execution of the Purchase/ServiceOrder, and any and all transactions contemplated by this Purchase/Service Order, it has and will apply effective anti-bribery and corruption reporting anddisclosure controls and procedures and has and will maintain internal accounting systems that are sufficient to show, in reasonable detail, alltransactions undertaken in relation thereto. Without prejudice to any other rights that the Seller/Contractor may have under law or otherwise, should theSeller/Contractor be considered to be in breach of any of the above provisions, Orpic may, upon written notice, immediately disqualify theSeller/Contractor from bidding, quoting, tendering, applying for or otherwise entering into the proposed Purchase/Service Order or terminate thisPurchase/Service Order (as the case may be) and refuse to allow the Seller to bid, quote, tender, apply or enter into any further or futurePurchase/Service orders, contracts or agreements with Orpic. The Seller/Contractor shall defend, indemnify and hold Orpic harmless from and againstany and all claims, damages, losses, penalties, costs and expenses arising from or related to, any breach of its commitments in this clause. Thisindemnity obligation shall survive termination or expiration of this Purchase/Service Order.

2.17 Business Ethics. In connection with Seller/Contractors performance of this Purchase/Service Order, Seller/Contractor undertakes that it willundertake and agree to act consistently with and to adhere to the principles of Orpic's General Business Principle in connection with Seller/Contractor'sperformance of this Purchase/Service Order. Failure to comply with this provision may constitute a Material Default giving rise to termination.

2.18 IP / Software. Where, as part of the performance under this Agreement, Contractor/Seller provides licensed software, Contractor/Seller shallprovide Orpic with a non-exclusive licence to use the software solely for Orpic's operational purposes. Orpic agrees to defend, indemnify and holdharmless Contractor from all damages and third party claims causes of action or damage arising from unauthorised use of the licensed software.

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2.19 HSE. Contractor/Seller shall ensure that all personnel required to enter Orpic's offices or sites in connection with this Agreement shall observeOrpic's Health, Safety and Environmental policies and regulations and Orpic's work site specific safety rules and policy. In particular the rules forPersonal Protective Equipment (PPE) will be followed. Any required PPE shall be provided by Contractor to its personnel at no additional cost to Orpic.Contractor/Seller shall ensure that all Goods delivered under this Purchase/Service Order shall be using vehicles suitable for the purpose of deliveringthe Goods, and shall at a minimum be registered commercially and include the insurances required under Omani law for commercially registeredvehicles. Orpic shall be entitled to reject the Goods, or the delivery thereof, if delivery is attempted in privately registered vehicles.

2.20 Patent Rights. Contractor/Seller shall release, defend, indemnify and hold Orpic harmless against all claims, liabilities, damages, losses, costs andexpenses (including lawyers# fees) concerning infringement or alleged infringement of any patent, registered design, trade mark, service-mark, copyrightor other intellectual property rights which may arise from anything done by or for Contractor/Seller in relation to the Services performed or Goodssupplied under the Service Order/Purchase Order.

2.21 Title and Risk. Title and risk in any Goods or Services provided as part of the Contract shall pass to Orpic on Completion.

2.22 Progress Checks, Inspections and Tests. Orpic shall be entitled to inspect the Goods or Services and any work thereon and to carry out any testsas it may require before delivery or acceptance. Seller/Contractor shall afford Orpic's representative every facility for such purposes, including access toContractor's site at all reasonable times. Any such inspection or tests shall not in any way relieve Seller/Contractor from any of its obligations under theAgreement.

2.23 Drawing and Technical Data. Contractor must comply with all general and specific requirements relating to drawings and technical data as set outin Purchase Order/ Purchase Contract. Any deviation from or modification to specifications of the Goods or Services as set out in Purchase Order/Purchase Contract is subject to Orpic's written approval. Seller/Contractor shall, when requested by Orpic, provide drawings and technical data forapproval and/or record purposes. Any such approval shall not imply that Orpic is responsible for the accuracy of any drawings or technical data otherthan its own.

2.24 Tax matters. The Seller/Contractor shall be responsible for reporting, filing, and payment of any taxes, duties, charges, or fees (and any relatedfines, penalties, or interest) imposed directly or indirectly onthe Contractor or the Contractor's employees and agents, as a result of the delivery of theScope of Work to Orpic in accordance with the provisions of this Agreement. The Contractor shall pay all taxes properly and lawfully assessed orimposed by any competent authority having jurisdiction in connection with the delivery of the Scope of Work to Orpic in accordance with the provisionsof this Agreement. Orpic shall have no liability whatsover to pay any taxes except any taxes properly assessed by any competent authority as beingpayable by Orpic in relation to this Agreement. The Contractor shall indemnify and keep indemnified Orpic against all liabilities incurred by Orpic as aconsequence of breach by the Contractor of any of the obligations under or in relation to this clause and all actions, proceedings, claims, damages,charges, costs and expenses whatsover in relation thereto.

2.25 Withholding Tax Deductions. The Seller/ Contractor shall be responsible for assessing and taking into account in its Price, the Contractor'spotential tax liability, including withholding tax liabilities, based on current Omani law and the Contractor's plans for executing the Agreement. In theevent that withholding tax is applicable in connection with the delivery of the Scope of Work by the Contractor to Orpic in accordance with the provisionsof this Agreement, the Contractor must: a) clearly separately specify which services are subject to withholding tax and which ones are not; and b)separately invoice charges for works or services which are subject to withholding tax. In the event that Orpic determnes, in line with Orpic#sinterpretation of Omani legal requirements, that withholding tax is applicable then Orpic will withhold, from sums otherwise due to the Contractor,amounts required by applicable law to be withheld and paid to the appropriate taxing authorities, and shall provide to the Contractor all receipts forpayment of the amounts. It shall be the Contractor's responsibility to provide to Orpic written confirmation fro m the Ministry of Finance, SecretariatGeneral for Taxation in order to verify that withholding tax is not applicable.

3. General Conditions Applicable for Procurement of Goods Only (Purchase Orders)

3.1 Purchase Order means the contract between Orpic and the Seller for the sale and purchase of the Goods in accordance with the followingdocuments which are to be read and construed in the following order of priority: a) Purchase Order; b) Particular Conditions; and then c) GeneralConditions.

3.2 Delivery Period means the date(s) on which the Goods must be delivered as set out in the Purchase Order.

3.3 Delivery Location means the location specified by Orpic for the Goods to be delivered as set out in the Purchase Order.

3.4 Goods means the goods as more particularly described in Purchase Order.

3.5 The Contract. Orpic agrees to buy and the Seller agrees to sell and deliver the whole of the Goods to Orpic in accordance with the terms of thisPurchase Order.

3.6 Seller's Obligations

3.6.1 Delivery. Seller expressly agrees that time is of the essence for delivery of the Goods. Seller shall inform Orpic well in advance about the planneddelivery of goods. If the Seller requires Orpic to return any packaging material to the Seller, that fact is clearly stated on the delivery note. Any suchpackaging material shall be returned to the Seller at the cost of the Seller. The Seller shall deliver the Goods: a) On the Delivery Date; b) To the DeliveryLocation; and c) During Orpic's normal business hours, or as instructed by Orpic; d) in accordance with the INCOTERMS set out in the Purchase Order.Delivery of the Goods shall be completed on the completion of unloading the Goods at the Delivery Location. Documents required for custom clearanceand delivery of goods: Airway bill or bill of lading; Invoice; Packing list; and Certificate of Origin.

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3.6.2 If the Seller: a) Delivers less than [95] % of the quantity of Goods ordered, Orpic may reject the Goods; or b) delivers more than [105]% of thequantity of Goods ordered, Orpic may at its discretion reject the Goods or the excess Goods, and any rejected Goods shall be returnable at the Seller'srisk and expense. If the Seller delivers more or less than the quantity of Goods ordered, and Orpic accepts the delivery, a pro rata adjustment shall bemade to the invoice for the Goods. The Seller shall not deliver the Goods in instalments without Orpic's prior written consent. Where it is agreed that theGoods are to be delivered by instalments, they may be invoiced and paid for separately. However, failure by the Seller to deliver any one instalment ontime or at all or any defect in an instalment shall entitle Orpic to the remedies set out in the Contract.

3.6.3 Supply & Packing Conditions. The Seller shall ensure that: a) The Goods are properly packed and secured in such a manner as to enable them toreach the Delivery Location in good condition; and b) each delivery of the Goods is accompanied by a delivery note which shows the date of thisPurchase Order, this Purchase Order number (if any), the type and quantity of the Goods (including the appropriate code number of the Goods to enableCustom Duty exemption, where applicable), special storage instructions (if any) and, if the Goods are being delivered by instalments, the outstandingbalance of Goods remaining to be delivered, together with any further information required as set out in the Purchase Order. Packets / boxes / otherpackaging must clearly show Purchase Order number and Orpic delivery location. Material Test Certificate or Conformance Certificate must be suppliedby Seller to Orpic on or before Delivery for the items indicated in the Purchase Order. All chemical and catalyst packages shall include: a) Theappropriate "HAZARD TYPE" and "HAZARD RATING LABEL" in bold letters; b) A lot number; c) Month & year of manufacture; d) Material expiry date ofthe product; e) Material Safety Data Sheet (MSDS); f) Certificate of quality. Seller must state country of origin of Goods. Seller must state theappropriate international code (M.S. Code) for customs exemptions. Seller must specify weight, physical dimensions, size, sea or air worthy packing andall other relevant information relating to the delivery of Goods. All material delivered under the Incoterm DDP Orpic's facility shall be delivered in opentop trucks / vehicles and not in closed containers.

3.6.4 Shelf Life Conditions. The Seller shall ensure that as of the later of the date of the delivery of the Goods or the Goods are made available for Orpic(or its nominated freight forwarder#s collection), the Goods shall have passed no more than 25% of the shelf life recommended by the originalmanufacturer for the Goods delivered. Orpic at its sole discretion,shall be entitled to reject the material for any failure to deliver the Goods in accordancewith the specification set under this Clause.

3.6.5 Acceptance and Defective Goods. After delivery of the Goods, Orpic shall have a period of fifteen (15) days to inspect the Goods and to carry outany testing to confirm that the Goods have been supplied and delivered in accordance with this Purchase Order. Upon satisfactory inspection of theGoods Orpic shall provide written confirmation to the Seller to confirm that the Goods have been accepted. If Orpic fails to provide written confirmation ofacceptance of the Goods within seventeen (17) days of receipt of the Goods in Orpic's facilities in the Sultanate of Oman then the Goods will be deemedto have been accepted. If at any point, including for a period of eighteen (18) months after acceptance of the Goods or, in the case of plant andequipment, after twelve (12) months of the date of commissioning, whichever expires first, Orpic discovers that any or all of the Goods do not conformwith their description or contain any defect then Orpic shall be entitled to reject the whole or any part of the Goods by notice to the Seller. On receipt ofnotice and at the option of Orpic the Seller shall either: a) Replace any or all of the Goods which do not conform with their description or which contain adefect; or b) Reimburse Orpic the whole or any part of the Price which was paid by Orpic to Seller and which relates to the rejected Goods. Anydefective or rejected Goods identified in a notice pursuant to this Clause 3.6.4 shall be collected and removed by the Seller within two weeks of thenotice. All costs associated with the collection and removal of any defe ctive or rejected Goods are for the Seller#s account.

3.6.6 Insurance. Without in any way limiting or detracting from the Seller#s liabilities under this Purchase Order or the Law, the Seller shall, at its owncost and expense, take out and maintain for the duration of the Seller#s liability under and in respect of this Purchase Order and the relevant insurancesas appropriate, issued by an insurance company registered in the Sultanate of Oman and reasonably acceptable to Orpic.

3.6.7 Penalties (Late Delivery). If specified in the Purchase Order and without prejudice to Orpic#s other rights and remedies under the Purchase Orderor at law, Seller shall become liable to pay Orpic an amount equal to 0.3 % of the total Purchase Order Value as defined in the Purchase Order for everyday or part thereof by which the Delivery Date specified in the Purchase Order is exceeded for any reason whatsoever, except for reasons attributable tofailure of Orpic to comply with the Purchase Order, up to a maximum of 10% of the total Purchase Order Value, or as amended and specified in thePurchase Order. If part of the Goods are delivered or can be put into useful operation the amount specified above shall be reduced proportionally. Theamount Seller is liable to pay to Orpic hereunder shall become due immediately the Goods are not delivered on the Delivery Date specified in thePurchase Order, without any notice or judicial intervention being required, and may be recovered by deduction by Orpic from Seller's invoices. In theevent a delay is caused by the gross negligence or willful of Seller no limitation as set out herein shall apply.

4. General Conditions Applicable for Provision of Services Only (Service Orders)

4.1 Agreement or Service Order means the contract between Orpic and the Contractor for the provision of Services in accordance with the followingdocuments which are to be read and construed in the following order of priority: a) Service Order; b) Particular Conditions; c) General Conditions; andthen d) Scope of Services.

4.2 Commencement Date shall be as set out in Service Order.

4.3 Completion means completion of the entire Services.4.4 Place for Performance means the location specified by Orpic for the Goods to be delivered as set out in the Form of Agreement.

4.5 Services means the services or work as more particularly described in the Scope of Services. #Work# or #Works# shall have the same meaning asServices

4.6 Purchase Order means an order issued in writing by Orpic at any time during the Service Order instructing the Contractor to perform the Servicesspecified in the order within the time frame specified in the order. If the term Call Off, Call-Out, Job, Job Order, Work Order or similar terms appear in theService Order, they shall have the same meaning as Purchase Order, unless the context requires otherwise.

4.7 Scheduled Completion Date means the date as set out in the Service Order and or Scope of Services by which Contractor shall reach Completion.

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4.8 Warranty Period means the period from the commencement of the Services up to one hundred and eighty days (180 days) after Completion duringwhich time Contractor shall remain liable for the correction of any defects in the Services.

4.9 The Contract. Orpic requires the Services to be performed and the Contractor has agreed to perform the Services on the terms and conditions setout in this Service Order.

4.10 Scope of Services. Contractor shall provide to Orpic the Services set out in Annex 3 (as that Annex may be amended from time to time by writtenagreement between the Parties).

4.11 Performance of Services and Warranties. Contractor shall exercise all reasonable skill, care and diligence in the performance of the Services andshall ensure that its staff exercises all reasonable skill, care and diligence. Contractor warrants that its staff involved in the provision of the Services willhave the requisite experience, qualifications and training to perform the Services in accordance with applicable industry practice, in a workman likemanner and which is reasonably satisfactory and acceptable to Orpic.

4.12 Contractor shall be liable to replace, at no cost to Orpic, within a reasonable time, any staff that Orpic reasonably considers do not have the abilityto adequately perform the Services or who have refused to comply with Orpic's reasonable instructions in respect of their conduct. Such staff shall beremoved from the assignment within 24 hours of Orpic issuing such instruction. The Services will be performed at the location(s) specified in the ServiceOrder. The Contractor shall ensure that its personnel shall: a) Comply with all health, safety and environmental rules and regulations applicable at thelocation of the Services; b) Comply with any instructions issued by Orpic relating to health, safety or the environment at the location of the Services; andc) Perform the Services in a safe and efficient manner and in accordance with any of Orpic's health, safety and environmental requirements, plans orpolicies as applicable. Contractor shall comply with all applicable laws, government orders, and regulations (whether of Sultanate of Oman or otherwise)in performing its obligations under this Agreement. Contractor shall be deemed to have satisfied itself before entering into this Agreement as to: a) Theextent and nature of the Services and all things necessary for the proper performance and completion of the Services in accordance with the terms ofthis Service Order; and b) The correctness and sufficiency of the sums, rates, and prices set out in the Service Order. Any failure by Contractor to takeaccount of matters which affect the Services shall not relieve it from its obligations under this Agreement. Contractor shall cooperate with Orpic and allthird party suppliers and service providers to Orpic, so as to ensure that Contractor performs the Services in a coordinated, effective and timely manner.

4.13 Schedule. Contractor shall commence performance of the Services on the Commencement Date, and shall proceed to perform the same with alldue diligence to achieve Completion on or before the Scheduled Completion Date. Contractor shall be responsible for the programming of the Servicesand for independently controlling its progress.

4.14 Penalties. If the Contractor has not commenced or completed the Services in time the Contractor shall be considered in default of his obligationsunder the Contract. If the Contractor fails to commence or complete the Services in time the Contractor shall pay the Company the Penalties/LiquidatedDamages as stated in the Service Order for whatever reason other than Force Majeure or a delay caused by Orpic. The levying of Penalties/LiquidatedDamages by the Company shall be without prejudice to any other rights and remedies of Orpic, which shall include the right to have work performed byanother contractor. Orpic shall have the right to terminate the Contract if the Contractor has not commenced or completed the Services by the time themaximum amount of Penalties/Liquidated Damages has become due. Where so provided in the Contract, Penalties/Liquidated Damages may also belevied in respect of delays in the commencement or completion of Services performed on a Call-Out basis.

4.15 Penalties (Late Delivery). If specified in the Purchase Order and without prejudice to Orpic#s other rights and remedies under the Purchase Order orat law, Seller shall become liable to pay Orpic an amount equal to 0.3% of the total Purchase Order Value as defined in the Purchase Order for everyday or part thereof by which the Delivery Date specified in the Purchase Order is exceeded for any reason whatsoever, except for reasons attributable tofailure of Orpic to comply with the Purchase Order, up to a maximum of 10% of the total Purchase Order Value, or as amended and specified in thePurchase Order. If part of the Goods are delivered or can be put into useful operation the amount specified above shall be reduced proportionally. Theamount Seller is liable to pay to Orpic hereunder shall become due immediately the Goods are not delivered on the Delivery Date specified in thePurchase Order, without any notice or judicial intervention being required, and may be recovered by deduction by Orpic from Seller's invoices. In theevent a delay is caused by the gross negligence or wilful failure of Seller no limitation as set out herein shall apply.

4.16 Defects Liability / Remedy Period. If defects in the Services are discovered by Contractor or otherwise brought to the attention of Contractor byOrpic either during the performance of the Services or within the Warranty Period, Contractor shall be responsible for remedying such defects at its owncost and/or for the cost of having such defects remedied. Contractor shall as soon as practicable upon discovery of any defect or upon receiving writtennotification from Orpic specifying any defect, remedy the same at its own expense by performing remedial work. If Contractor fails within a reasonabletime to perform the remedial work as required by Orpic, Orpic shall have the right to have the necessary remedial work performed by other contractorsor sub-contractors. Orpic shall recover from Contractor all costs associated with remedying such defect, either directly from Contractor or by deductingsuch costs from any monies due or which become due to Contractor. Orpic shall use reasonable endeavours to mitigate such costs. Contractor'sfinancial liability in respect of costs incurred by Orpic shall be limited to the actual costs incurred by Orpic and in any event to a sum not greater than onehundred percent (100%) of the Price.

4.17 Call-Off / Purchase Order. If the Scope of Services includes provisions on call-offs, Orpic shall have the right to order Services on a call-off basis byissuing a Purchase Order and the Contractor shall perform the Service in accordance with Contract and time schedule specified in the Purchase Order.

4.18 Orpic shall have the right to modify or extend the Services specified in a Purchase Order at any time by means of a revision to a Purchase Order.Notwithstanding the expiry or early termination of the Agreement, Contractor shall not abandon any Services in progress and shall complete suchServices in accordance with Orpic's instructions. The terms and conditions of Agreement shall remain in full force and effect during the period requiredto complete these Services. Orpic does not guarantee any minimum quantity of call-off, nor does Orpic undertake to exclusively use the Contractor forthe performance of call-off Services.

4.19 Party Representatives. Orpic may appoint an Orpic Contract Manager who shall be authorised to act for and on behalf of Orpic in relation to thisAgreement. Contractor shall appoint a Contractor Representative who shall be authorised to act for and on behalf of Contractor in relation to this

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Agreement.

4.20 No Partnership. Nothing in this Agreement, and no action taken under this Agreement: a) Creates a partnership; b) Creates a relationship ofprincipal and agent between any of the parties; or c) Otherwise authorises any party to bind any other party.

4.21 Licences and Permits. Contractor shall obtain and maintain, at its own risk and expense, such authorisations, permits and licences as may benecessary for the performance of the Services and which are required to be obtained and maintained in Contractor's name.

4.22 Insurance. Without in any way limiting or detracting from Contractor's liabilities under any other provisions of this Agreement or the law, Contractorshall on or before the Commencement Date, at its own cost and expense, take out and maintain for the duration of the Contractor's liability under and inrespect of this Agreement and the Law, each of the insurances set out below, issued by an Insurance Company registered in the Sultanate of Oman andreasonably acceptable to Orpic: a) Construction/Erection All Risks insurance covering the Permanent Work; b) adequate third party liability insurance tocover all third party liabilities arising under this Contract including the Existing Property; c) any insurance which may be required by law for or withrespect to the Contractor Personnel; d) adequate liability insurance for motor vehicles and mobile equipment (owned, non-owned or hired units)employed by the Contractor or Orpic supplied Equipment employed by the Contractor or any Subcontractor in connection with the performance of theContract.

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Appendix : Form of Advance Payment Bond

Oman Oil Refineries and Petroleum Industries Company SAOCP.O. Box 3568Postal Code 112 RuwiSultanate of Oman

Advance Payment Bond No _ _ _ _ _ _ _ _ _ _ _ _

Whereas M/s . _ _ _ _ _ _ _ _ _ _ (Hereinafter called the Supplier) has been awarded a Contract dated _ _ _ _ _ _ _ _ .for delivery and completion of _ _ _ _ _ _ _ _ _ Project as described in the contract for the total ContractPrice of R.O. _ __ _ _ _ _ _ _ _ (Omani Rials _ _ _ _ _ _ _ _ _ _ _ _ _ Only) and in consideration of your making an advance payment ofR.O. _ _ _ _ _ _ _ . (Omani Rials _ _ _ _ _ _ Only) to the Supplier being 10.% of the Contract Price, by this bond, we _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ whose address is _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ guarantee to pay youa sum not exceeding R.O. _ _ _ _ _ _ (Omani Rials _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Only) onyour first written demand without any reference to or contestation on behalf of the Supplier.

It is understood that our liability towards you will be progressively reduced by the amount repaid to you by the Supplier ascontained in the Certificates and Payment against the said advance payment.

The bond will be effective from _ _ _ _ _ _ _ _ . and shall be valid until _ _ _ _ _ _ _ , or until the amount of advancepayment is fully recovered, whichever occurs later.

This bond should be returned to us upon its expiry or upon fulfillment of our undertaking whichever is the earlier.

Authorised Signatories(To be issued by a locally registered bank)Place:Date:

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