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Doc. Ref.: MM-YAD-00-DORI-474018

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Revision: 01 Rev Date:12-Jul-2011Instrument Design & Installation

Discipline:INS Document Type:SPE

Phase: FE System / Subsystem:04 Equipment Type:XP Status:AFD Class:1 Page2of 65

This document is the property of TOTAL E&P MYANMAR. It must not be stored, reproduced or disclosed to others without written authorisation from the Company.

R:\652301\Typing\DOCS\NATIVE\DOCS\47-Instrumentation (new doc)\MM-YAD-00-DORI-474018_rev01.doc

TABLE OF CONTENT

1 General ........................................................................................................................................... 6

1.1 Purpose.............................................................................................................................. 6

1.2 Field of application............................................................................................................. 6

1.3 Applicable Contract Clauses.............................................................................................. 6

1.4 General Requirements for installation ............................................................................... 6

1.5

Compliance With Project Basic Specification .................................................................... 7

1.6 Reference Documents ....................................................................................................... 8

1.6.1 Project Documents ...............................................................................................................................................8

1.6.2 Existing Documents ..............................................................................................................................................8

1.6.3 COMPANY General Specifications.......................................................................................................................9

1.6.4 Standard and Codes............................................................................................................................................. 9

1.7 Use of Language and Abbreviations.................................................................................. 9

1.8 Abbreviations ................................................................................................................... 10

1.9 Responsibilities ................................................................................................................ 11

2 Environmental conditions .......................................................................................................... 11

2.1

Outside Conditions for Field Instrumentation................................................................... 11

2.2 Inside Conditions for Instrumentation .............................................................................. 11

3 General principles ....................................................................................................................... 12

3.1 General ............................................................................................................................ 12

3.2 System of Units................................................................................................................ 12

3.3 Utilities.............................................................................................................................. 12

3.3.1 Instrument Air...................................................................................................................................................... 12

3.3.1.1 General rules............................................................................................................................................ 12

3.3.1.2 Field construction.....................................................................................................................................12

3.3.2 Hydraulic Oil Supply ...........................................................................................................................................13

3.3.3

Electrical Power Supplies ................................................................................................................................... 13

3.3.4 Earthing System.................................................................................................................................................. 14

4 Specification ................................................................................................................................ 15

4.1 Electrical classification..................................................................................................... 15

4.2 Signal Transmission......................................................................................................... 15

4.2.1 Pneumatic transmission...................................................................................................................................... 15

4.2.2 Electrical transmission ........................................................................................................................................16

4.3 General requirements ...................................................................................................... 16

5 Process Units Information.......................................................................................................... 18

5.1 Flow Instruments.............................................................................................................. 18

5.1.1

General ............................................................................................................................................................... 18

5.1.2 Gas Flow.............................................................................................................................................................19

5.1.3 Liquid Flow..........................................................................................................................................................19

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5.1.4

Use of Hook-Up Drawings ..................................................................................................................................195.1.4.1 Short Mounting (Short Impulse Lines) used mainly for local indicators ................................................... 19

5.1.5 Other Flow Measuring Devices...........................................................................................................................20

5.1.5.1 Meters ...................................................................................................................................................... 20

5.1.5.2 Magnetic Flowmeters...............................................................................................................................20

5.1.5.3 Rotameters............................................................................................................................................... 20

5.1.5.4 Specific Metering (Fiscal, Turbine, Ultrasonic, Etc...) .............................................................................. 20

5.2 Level Instruments............................................................................................................. 21

5.2.1 General ............................................................................................................................................................... 21

5.2.2 Pressure transmitter ...........................................................................................................................................22

5.2.3 Torque Tube transmitter .....................................................................................................................................22

5.2.4 Level gauge glasses ...........................................................................................................................................22

5.2.5 Level Switches.................................................................................................................................................... 23

5.2.6

Nucleonic Level Gauges .....................................................................................................................................23

5.3 Pressure instruments....................................................................................................... 23

5.3.1 Pressure and Differential Pressure transmitter ...................................................................................................23

5.3.2 Pressure switches:.............................................................................................................................................. 23

5.3.3 Pressure gauges.................................................................................................................................................23

5.3.4 Pressures Taps................................................................................................................................................... 24

5.3.5 Mounting ............................................................................................................................................................. 24

5.4 Temperature Instruments................................................................................................. 24

5.4.1 Temperature transmitter .....................................................................................................................................24

5.4.2 Thermometer ...................................................................................................................................................... 25

5.4.3 Thermowell ......................................................................................................................................................... 25

5.4.4

Temperature Switches........................................................................................................................................26

5.5 Miscellaneous Measuring Instruments ............................................................................ 27

5.5.1 Tachometers....................................................................................................................................................... 27

5.5.2 Vibrations............................................................................................................................................................ 27

5.5.3 Displacement Or Axial Thrust ............................................................................................................................. 28

5.6 Control Valves.................................................................................................................. 28

5.7 ON/OFF Valve Characteristics......................................................................................... 28

5.8 Relief And Discharge Valves ...........................................................................................28

6 Instrument accessibilty............................................................................................................... 29

6.1 General accessibility rules ............................................................................................... 29

6.2 Essential accessibility rules. ............................................................................................29

6.3 Testing ............................................................................................................................. 30

7 Instrument Hook-Up.................................................................................................................... 31

8 Technical Room Equipment ....................................................................................................... 33

9 Electrical Wiring Installation ...................................................................................................... 33

9.1 General ............................................................................................................................ 33

9.2 Marking ............................................................................................................................ 33

9.3 Offshore Main Routing Cable Trays ................................................................................ 34

9.3.1

General ............................................................................................................................................................... 349.3.2 Cable Trays......................................................................................................................................................... 35

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9.4

Offshore Cable Transits in Modules, Premises, Etc. ....................................................... 35

9.5 Junction Boxes................................................................................................................. 35

9.6 Cable Glands ................................................................................................................... 36

9.7 Junction Boxes Terminals................................................................................................ 36

9.8 Wiring Precautions........................................................................................................... 37

9.8.1 Precautions Against Electromagnetic Interferences........................................................................................... 37

9.8.2 Spare Lengths..................................................................................................................................................... 37

9.8.3 Protection of Electronic Circuits .......................................................................................................................... 37

9.8.4 Segregation......................................................................................................................................................... 38

9.8.4.1 Segregation of Cables and Junction Boxes.............................................................................................39

9.8.4.2 Segregation of Cables Runs .................................................................................................................... 39

9.8.4.3

Spacing .................................................................................................................................................... 40

9.8.5 Cable Ties...........................................................................................................................................................40

9.8.6 Cable Ends ......................................................................................................................................................... 40

10 Marshalling cabinets ................................................................................................................... 41

10.1 General ............................................................................................................................ 41

10.2 Environmental conditions................................................................................................. 41

10.3 Quantity of cabinets and location..................................................................................... 41

10.4 Marshalling Cabinets Purpose......................................................................................... 41

10.5 Cabinet mechanical requirements ...................................................................................42

10.6

Cabinet equipment........................................................................................................... 43

10.6.1 Terminals ............................................................................................................................................................ 43

10.6.2 Cabling and Marking...........................................................................................................................................43

10.6.3 Earthing............................................................................................................................................................... 44

10.7 Spare capacity ................................................................................................................. 45

10.8 Factory acceptance test (FAT)......................................................................................... 45

11 Selection of equipment according to area classification........................................................ 46

11.1 Hazardous areas.............................................................................................................. 46

11.2 Types of Safety Equipment.............................................................................................. 46

12 Weatherproofing.......................................................................................................................... 47

12.1 Sun Protection ................................................................................................................. 47

12.2 Rainproofing & Salt Protection......................................................................................... 47

12.3 Marine Environment Protection ....................................................................................... 47

12.4 Painting............................................................................................................................ 47

12.5 Tropicalisation.................................................................................................................. 48

13 Instrument fireproofing............................................................................................................... 49

13.1 Purpose............................................................................................................................ 49

13.2 Valving, Solenoid Valves ................................................................................................. 49

14

Storage of the instruments......................................................................................................... 50

15 APPENDIX 1 - Instrumentation piping classes......................................................................... 51

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15.1

General ............................................................................................................................ 51

15.2 Environmental conditions................................................................................................. 51

15.3 Tubing & fitting requirement............................................................................................. 51

15.4 Service class index .......................................................................................................... 52

15.5 Instrument piping class tables.......................................................................................... 54

15.5.1 CLASS K1...........................................................................................................................................................54

15.5.2 CLASS K2...........................................................................................................................................................55

15.5.3 CLASS K5...........................................................................................................................................................56

15.5.4 CLASS K10.........................................................................................................................................................57

15.5.5 CLASS K20.........................................................................................................................................................58

15.5.6

CLASS K21.........................................................................................................................................................59

16 APPENDIX 2 Instrumentation symbolisation and identification.......................................... 60

16.1 Introduction ...................................................................................................................... 60

16.2 Codes and Standards applicable.....................................................................................60

16.3 Instrumentation symbols on P&IDs................................................................................. 60

16.4 Identification..................................................................................................................... 60

17 APPENDIX 3 Wiring and tagging rules................................................................................... 62

17.1 General ............................................................................................................................ 62

17.1.1 Scope.................................................................................................................................................................. 62

17.1.2

Reference Documents ........................................................................................................................................62

17.2 Identification and Labelling .............................................................................................. 62

17.2.1 Control Room......................................................................................................................................................62

17.2.2 Instrument Technical Room (ITR)....................................................................................................................... 62

17.2.3 Temporary Control Room Equipments ............................................................................................................... 62

17.2.4 Temporary Cabinet in Jack-up Instrument Technical Room...............................................................................63

17.2.5 Cabinet in QP2 MSF Instrument Technical Room.............................................................................................. 63

17.2.6 Cabinet and Local Panel in the Unit ................................................................................................................... 63

17.2.7 Identification of Junction Boxes .......................................................................................................................... 63

17.2.8 Identification of Cables/Multicore Cables............................................................................................................64

17.2.8.1 Multi-pair cable between Technical Room and Junction Box or Local Panel .......................................... 65

17.2.8.2 Individual Cable between Junction Boxes or Local Panel and Instrument .............................................. 65

17.2.8.3 Cable between Marshalling Cabinet and PCS, ESD and F&G Systems ................................................. 65

17.2.9

Identification of Terminal Blocks ......................................................................................................................... 65

17.2.9.1 Inside Marshalling Cabinet....................................................................................................................... 65

17.2.9.2 Inside PCS, ESD, F&G Systems Cabinets .............................................................................................. 65

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1 General

1.1 Purpose

This specification covers the minimum design, detail or package engineering, manufacture installation andtesting for the YADANA SUBSIDENCE PROJECT (YSP).

For easier understanding, the term installation team is used herein to denote the construction or hook-upCONTRACTOR, as well as the Supplier of packages and modules and related equipment. Whenever he isrequired to install an instrument as part of a supply contract to which any section of this specification applies.

1.2 Field of application

This specification applies to the instrument design & installation for YSP.

1.3 Applicable Contract Clauses

This document covers the essential requirements for the specification, evaluation, detail design, installationof instrumentation systems but should be considered as only a part of the overall Specifications for theproject.

For all detailed design work, CONTRACTOR shall be required to refer to and comply with the JobSpecifications, General Specifications and drawings listed in paragraph 1.6 of this document

Moreover CONTRACTOR shall ensure that the specifications are compliant with in the supply ofsubcontracted assemblies and subassemblies and in the subcontracts themselves.

The general requirements contained in the Project Basic Specifications are designed to define the following:

at the design stage, the choice of hardware and equipment, and the documents to be supplied

at the procurement stage, the purchasing requirements and requirements for inspection insuppliers premises

at the construction stage, the principles of installation, inspection, acceptance and commissioning.

The Project Basis Specifications should therefore be taken as a minimum requirement, based on the currentrules of the art; accordingly, CONTRACTOR may submit to COMPANY for approval and all alternativesolutions deemed to provide technical or economic improvement over existing practice.

1.4 General Requirements for installation

CONTRACTOR has overall responsibility for supervision, purchasing, labor and overhead involved in theinstallation of the instruments of the project and their related hardware, including wiring, power supplies andso on, as well as the relevant temporary utilities and services and consumable supplies required.

Instrument installed shall be fit for purpose and fully certified.

Qualified personnel will be used for all instruments installation work.

All work shall be carried out in a safe tidy manner with high level of work manship.

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All personnel involve in making-up compressoring fitting will have intended the compression fittingmanufacturer training course.

The following general specifications apply:

All instruments installed on piping, such as meters, valves, flow measuring orifices, thermowellsand the like shall be installed by the Piping team, under the supervision of an Instrumentengineer. Adjacent piping shall be firmly supported and in no way impart any stress to theinstruments and instruments to process links shall be supported so as not to stress theinstruments,

The same rules apply to heavy equipments such as torque tube levels and tank level gauges orother equipment requiring special lifting devices for installation,

All tubing shall be adequately supported throughout the installation, Instruments shall be mounted such as to fully comply with accessibility rules (refer to section 6),

Installation of instrument supports or line supports shall be performed according to goodconstruction practices (hook-up drawing and specific Vendor requirement), especially where thereis a risk of corrosion and when the supports are secured onto fireproofed structures,

All instruments installed in a process unit shall be tight construction type or suitably tightened bymeans of adequate protection. Instruments shall be mandatorily protected after installation duringconstruction phase,

All explosion proof and intrinsically safe equipment shall be installed according to CENELECregulation,

1.5 Compliance With Project Basic Specification

For all detailed design work, CONTRACTOR shall have in hand and be fully informed of all the Project BasicSpecifications and shall ensure their full application.

In the event of disagreement with any requirement of the Instrument Design and Installation or Jobspecifications, CONTRACTOR shall submit to COMPANY a written request for exemption, clearly stating thefollowing:

The specification section and paragraph which is the object of the disagreement;

The equipment concerned ( type, quantity);

The justification for the request (cost, time, operating advantages).

The final decision shall be taken by COMPANY in the form of:

Either a refusal to exempt,

Or an exemption for the equipment concerned.

Each exemption shall mandatory be notified in writing and each written notice of exemption shall cover onlya single exemption. No other form of exemption, such as implied from a verbal discussion, a meeting or theapproval of a drawing or other such document shall be deemed valid.

Granting by COMPANY of an exemption shall not be construed as in any way relaxing the responsibility ofthe party requesting the exemption.

The priority regarding the project basic documents is the following one:

1. Statutory regulations

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2. Material requisition

3. Specification and Data sheet

4. Job specifications

5. General specification

In the event of any conflict between these documents or any others specification or with an applicable codesand standards, written clarification shall be sought from COMPANY before proceeding.

1.6 Reference Documents

1.6.1 Project Documents

[1] MM-YAD-00-DORI-474017 Instrument and control philosophy

[2] MM-YAD-00-DORI-474020 Instrument cables specification

[3] MM-YAD-00-DORI-474026 Instrumentation for package specification

[4] MM-YAD-00-DORI-474021 Instrument earthing principles

[5] MM-YAD-00-DORI-474019 Instrument power distribution cabinet specification

[6] MM-YAD-00-DORI-474024 Control valve specification

[7] MM-YAD-00-DORI-474023 On/Off valves actuators and control panels specification

[8] MM-YAD-00-DORI-474025 Safety valves Specification

[9] MM-YAD-00-DORI-434003 General - Specification - Equipment Design Conditions

[10] MM-YAD-20-DORI-491003 HVAC basis of design

[11] MM-YAD-00-DORI-434001 General - Piping Material Classes

[12] MM-YAD-00-DORI-484004 Specification for Earthing and Bonding

[13] MM-YAD-00-DORI-424001 General Safety Concept

[14] MM-YAD-00-DORI-479001 Instrument hook up standards

[15] MM-YAD-00-DORI-474007 Instrumentation Symbolisation and Identification

Specification

1.6.2 Existing Documents

[16] GS-203248-GEN-IN-0012 Hydraulic Power Unit specification

[17] DB-203248-GEN-PM-0010 Equipment Numbering Procedure

[18] PID-203248-GEN-PR-0001 PID Symbols Process and Instrumentation





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1.6.3 COMPANY General Specifications

[24] GS-EP-ELE-031 Design of earthing & bonding system

[25] GS-EP-ELE-311 Cable trays/ladders

[26] GS-EP-INS-101 Instrument engineering supply and construction - general

[27] GS-EP-COR-350 External protection of offshore and coastal structures andequipment by painting

1.6.4 Standard and Codes

The instrument design & installation shall fully comply with all applicable sections of the latest editions of thefollowing codes and standards (and their current amendments):

API RP 526 Flanged Steel Pressure Relief Valves

API 550 P1 Process Instrumentation & Control-Section 1: Flow

API 670 Machinery Protection Systems

ASME PTC 19.3 Temperature Measurements

CEI 79-10 Classification of Hazardous Areas

IEC 60079-14 Explosive Atmospheres - Part 14: Electrical Installations Design, Selection AndErection

ISO 5167 Measurement Of Fluid Flow By Means Of Pressure Differential Devices

ISO 5168 Measurement Of Fluid Flow - Procedures For The Evaluation Of Uncertainties

NACE MR 01-75 Petroleum And Natural Gas Industries - Materials For Use In H2s

NACE 16-38

NFC 20455 Test Methods-Fire Behaviour-Glow Wire Test-Inflammability And Ability To BeExtinguished.

EN 50014 Electrical Apparatus For Potentially Explosive Atmospheres - General Requirements

EN 50018 Electrical apparatus for potentially explosive atmospheres - flameproof

EN 50019 Electrical Apparatus For Potentially Explosive Atmospheres - Increased Safety "E"

1.7 Use of Language and Abbreviations

Throughout this specification, the words will, may, should, shall when used have specific meanings asfollows :

will is used normally in conjunction with an action by COMPANY

may is used where alternatives are equally acceptable

should is used where a solution is preferred

shall is used where a provision is mandatory

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1.8 Abbreviations

AC : Alternative CurrentAPI : American Petroleum InstituteASME : American Society of Mechanical

EngineersBDV : Blowdown ValveCCTV : Closed Circuit TeleVisionCPU : Central Processing UnitCR : Control RoomDC : Direct Current

DCS : Distributed Control SystemDHSV : Down Hole Safety ValveEEX : Explosion ProtectionESD : Emergency ShutdownESV : Emergency Shutdown ValveF&G : Fire & GasHP : High PressureHPU : Hydraulic Power UnitHRS : Hardwire Relay SystemHVAC : Heating, Ventilating and Air

ConditioningI/O : Input/OutputICSS : Integrated Control and Safety

SystemIE : Instrument EarthIEC : International Electrical CommissionIP : Ingress ProtectionIPE : Instrument Protective EarthIR : Infra RedIS : Intrinsic SafetyISE : Intrinsically Safe EarthISO : International Standard OrganisationITR : Instrument Technical RoomJB : Junction BoxL : LocalLCP : Low Compression Platform

LED : Light Emitting DiodeLP : Local Panel or Low PressureMC : Marshalling cabinetMCB : Main Circuit BreakerMCC : Motor Control CenterMCP : Medium Compression PlatformMCT : Multi Cable TransitMP : Medium PressureMTBF : Mean Time Between FaIlureMTTR : Mean Time To Repair

NACE : National Association of CorrosionEngineers

NC : Normally ClosedNO : Normally OpenOC : Operator ConsoleOCD : Operator Control DeskOD : Overall DiameterOPPS : Over Pressure Protection SystemOS : Operator Station

PA/GA : Public Adress/General AlarmPC : Personal ComputerPCC : Pipeline Control CentrePCS : Process Control SystemPDB : Power Distribution BoardPDC : Power Distribution ControlPE : Protective EarthPLC : Programmable Logic ControllerPP : Production PlatformPSS : Plant Safety SystemQP : Quarter PlatformRTD : Resistance Thermometer DetectorRTU : Remote Terminal Unit

SCADA : Supervisory Control And DataAcquisition

SDV : Shutdown ValveSPDT : Single Pole Double ThrowSS : Stainless SteelTB : Termination BoardTMR : Triple Modular RedundantTSO : Tight Shut-offUCP : Unit Control Panel (Remote Package

Control)UMV : Upper Master ValveUPS : Un-interruptible Power SupplyUV : Ultra-Violet

VAC : Volt Alternative CurrentVDC : Volt Direct CurrentVDU : Video Display UnitVHP : Very High PressureWHPU : Wellhead Hydraulic Power UnitWSC : Wellhead Safety CabinetWP : Wellhead PlatformWV : Wing ValveXV : Process ON/OFF ValveYSP : Yadana Subsidence Project

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1.9 Responsibilities

CONTRACTOR shall be responsible for the engineering, procurement, supply, installation, commissioning ofthe Instrument design & Installation for YSP.

During detailed engineering, CONTRACTOR shall produce individual datasheets, drawing or hook-up foreach additional Instrument.

2 Environmental conditions

2.1 Outside Conditions for Field Instrumentation

The criteria defined inside this paragraph are based on the project document Ref. [9] General - Specification- Equipment Design Conditions.

Outside temperatures are:

Maximum 33C

Normal 27C

Minimum 20C

Relative humidity average 70 % continuously.

The field instrument shall be protected against corrosion and suitable for installation with salt laden airconditions severe marine. They must accept a direct sunlight temperature of 80C.

All components shall be constructed of materials resistant to corrosion due to the process fluid with whichthey will or may come into contact internally, and to ambient air environment to which they are externallyexposed. For design purpose, the atmosphere of the entire plant area shall be considered to contain traceamounts of hydrogen sulphide at all times. The use of copper bronze and other copper alloys, except monelis not permitted.

2.2 Inside Conditions for Instrumentation

The criteria defined in this paragraph are based on the project document Ref. [10] HVAC Basic of Designand are available for all platforms.

Inside temperatures are:

Maximum 25,5C

Normal 24C

Minimum 22,5C

Relative humidity is between, 35 % and 55 %. Air inside technical room is considered clean, free ofdust and without salt laden.

In case of failure of HVAC, temperature will increased of 5C per hour, with a maximum of 45C. Relativehumidity can be equal to 86 %.

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3 General principles

3.1 General

The instrumentation designed and implemented for measurement and control purposes shall satisfy twomain criteria: optimal operation of the process units and minimum cost of the installation through start-up,operation and maintenance.

CONTRACTOR shall use every opportunity to reduce site work including assembly, to a minimum, especiallyif the site is offshore or in an unhealthy area.

Instruments and instrument installation methods shall be selected in view of their simplicity, reliability andease of maintenance.

3.2 System of Units

For all projects, engineering calculations results, instrument ranges, control settings shall be presented toCOMPANY in SI units like defined in the project document Ref. [9] General - Specification - EquipmentDesign Conditions.

Any exception to SI units shall be notified to CONTRACTOR;

For piping, tubing and fittings where nominal bore sizes will be imperial.

3.3 Utilities

3.3.1 Instrument Air

3.3.1.1 General rules

The dewpoint of the instrument air is 5C at 8 barg.

No quick-disconnect couplings shall be authorised anywhere in the instrument air network

lnstrument air shall be provided by compressors through dryers.

The compressors and air network shall be sized for design pressure of 11 barg and 8 barg (normal pressure)

at any point in the network from the dryers, at a normal air consumption.

Maximum operating header pressure : 7 barg

Minimum operating header pressure : 4 barg

3.3.1.2 Field construction

CONTRACTOR Installation Team shall be in charge of instrument air supply, including installation of sub-headers and distributors after the header shut-off valves installed on the main header by the pipe fitter.

This installation work shall include provision of sub-headers and supply piping up to individual air users, orthe installation of distribution manifold pipes together with their sub-header feeder and air user feeder lines.

Air supply sub-headers shall have minimum diameters as follows, depending on the number of air usersserved:

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1/2 for 5 air users maximum,

3/4 for 6 to 12 air users maximum,

1 for 13 to 20 air users maximum,

1 1/2 for 21 to 50 air users maximum.

Different size user feeders may be required for air supplies to shut down valve actuators.

Instrument air lines (3/8 tubing) shall not be longer than 20m.

Tubes shall be adequately supported to avoid deformation and other unnecessary stresses.

Piping supplied and installed shall be in accordance with instrument piping classes.

Sub-headers shall be equipped with tees and caps for purging the low points and dead arms.

Spare connections shall be provided and equipped with shut-off valves and blank flanges or caps.

Piping rack connections shall be at least 1 and generally 1. The minimum sizing of connections for allother purposes shall be 1/2. Connections on horizontal piping shall be made to the upper generatrix.

3.3.2 Hydraulic Oil Supply

Oil used on the platform shall be supplied through an hydraulic network

All equipment will be designed for oil TOTAL AZOLA complete oil references will be defined during detailengineering and submitted to COMPANY approval. Wherever possible the same reference will be selectedon the totality of this project.

Hydraulic Oil is be supplied through a hydraulic network from a Central Hydraulic Power Unit (HPU), refer tothe existing document Ref. [16] Hydraulic Power Unit specification.

Normal MP header pressure : 104 barg

Maximum MP header pressure : 110 barg

Minimum MP header pressure : 85 barg

Header MP Design Pressure : 150 barg

CONTRACTOR installation team shall be in charge of:

All furnishing and connections between hydraulic actuators local control station and isolatingvalves located near each hydraulic valve (1.50 m maximum).

Tubing and fitting supplied shall be in accordance with appendix 1

Diameter of piping shall be defined during detail engineering.

All instrument tubing return lines shall be independent for different oil pressures/services.

3.3.3 Electrical Power Supplies

Production and distribution of electrical power for instruments shall be through one dual 220V AC UPSdesigned in accordance with COMPANYs electrical specification.

Specific cabinet inside technical room will be dedicated to power instrument distribution for systems and fieldinstruments. Refer to project document Ref. [5] "Instrument power distribution cabinet specification".

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Instruments package will be powered from these cabinets when required in order to allow ease of isolation.

The voltages available for instrumentation on this project are:

230 V AC 10 % 50 Hz 0,5 % (Ph + N) impedance neutral earthing

24 V DC 10 %

No significant additional power supply will be necessary at QP control room and PP technical room.

3.3.4 Earthing System

All electrical devices shall be ground to protect personnel and equipment against electrical discharges.

Refer to the project document Ref. [4] Instrument earthing principle.

Instrument earthing is identified as three different systems but they shall not have different earthing bar in thesame marshalling or cabinet. Nevertheless it shall be necessary to apply the IEC 60079-14 in case ofintrinsically safe circuit.

Three different instrument earthing:

1. Instrument Protective Earth (IPE): for earthing frames, jackets, plates, cable armouring (forprotection of personnel)

2. Instrument Earth (IE): for earthing voltage references of electronic systems and cable shieldsand/or screens

3. Intrinsically Safe Earth (ISE): for earthing intrinsically safe devices (shields and/or screens, voltagereferences, etc.)

Cable armour shall be and/or screen shall be earthed at both ends except in case of intrinsically safe circuitand low voltage signals such as thermocouple signals

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4 Specification

4.1 Electrical classification

To conform to the existing Yadana site practice all field instruments shall be of the intrinsically safe typeEexi" certified with the exception of:

solenoid valves,

flammable gas detectors,

UV/IR flame detectors,

which may be Eexd.

Electronic instruments and their connections shall comply with the relevant area classification requirements(refer to section 11 of this document).

For installation of the instruments, ATEX directive shall be followed.

Electronic instruments locally mounted shall be Eexi according to CENELEC standard. Eexd will be usedexceptionally if a specific instrument cannot be Eexi".

Intrinsically safe circuits shall be installed in accordance with CENELEC regulation, individual instrument in aloop shall be IS certified as well as the connecting cables.

The loop (closed or opened) shall be tested by CONTRACTOR to verify that lS characteristics are achieved.

An IS loop certificate shall be issued by a certifying authority on CONTRACTOR request and expenses.

The junction boxes will be Eexe (as they are fitted with terminals only).

Attention is drawn to the effect of long cable run for which reactance / capacitance shall be taken intoaccount for Eexi characteristics.

The limit switch have to be proximity type, EE.xi", hermetically sealed ideally suitable for use in Zone I ,group II A T3.

Contact rated at 24 V DC will be maximum 1A.

4.2 Signal Transmission

4.2.1 Pneumatic transmission

All components of a pneumatic measuring system shall be selected with a 0.2 - 1 bar range.

Pneumatic signals shall not be used on lines more than 100 m long from transmitter to controller on the onehand and from controller to actuator on the other hand.

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4.2.2 Electrical transmission

In the interest of flexibility and standardisation, the components shall be in accordance with followingcommon characteristics:

All sensors/transmitters and controlled final receivers shall be 4-20 mA, 24 VDC.

Sensors/transmitters and control valve positionners shall be "Smart" type with a communication protocolbased on the HART standard.

Those connected to the ESD system will have their smart facilities disabled by a combination of hardwired

jumpers and instrument dedicated passwords.

For smart safety related instruments, access to configuration shall be protected by hardware means on theinstrument itself.

Instruments using mercury are forbidden.

Electrical signals shall be transmitted over individual cables to a junction box, then over a multi-pair cable toa device or to the marshalling cabinet in technical room.

From the marshalling cabinet termination assemblies to the PCS and the PSS I/O modules, cables withconnectors shall be used.

4.3 General requirements

Local (field) instruments when necessary shall be provided with or NPT electrical connectionsequipped with cable mounting glands. Glands shall comply with the area classification.

All CENELEC approved instrument, boxes or accessories must be labeled.

Instruments installed on the site shall have Ingress Protection lP65 minimum and be designed for corrosivehumid or salt air environment depending on the project.

They shall be coated with the manufacturers standard paint (except if the latter does not meet the projectsenvironmental constraint), in the manufacturers standard colour (except red).

They shall be generally provided for installation on 2 pipe (except for pressure gauges and instrumentsscrewed directly on a tap).

Instruments shall be provided with an engraved stainless steel tag number plate bearing their loopidentification number.

Local recorders shall be avoided.

For PCS, Electronic transmitters shall be two wire smart type, capable of supporting full digitalcommunications according to selected PCS. Smart transmitters with digital calibration signal surimposed on2 wires 4-20 mA signals shall be the rule, to allow remote calibration from technical room.

For PSS system standard 2 wires electronic transmitters supported 4-20 mA signal shall be used. Thesetransmitters will have their smart facilities disabled by a combination of hardwired jumpers and instrumentdedicated passwords

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Process and Emergency Shut-down measure will be given by dedicated instrument connected on separatetapping.

All instruments will be installed with vent and drain facilities, and for hazardous and/or polluting fluids thevent/drain of instruments shall be piped to the vent/drain networks.

Instruments shall be insulated and/or heated and/or fitted with process separators when fluids characteristicsand/or temperature conditions can alter performance and reliability of the system.

The measurement capillaries shall be provided with heat insulation and mechanical protection.

In case of dual transmitters (one for Safety, one for Control) for the same process measurement, they shallhave same range and span and the process connections will be fully independent but shall be close togetherto allow comparison of measurements.

On vessels, level transmitters tapping points shall be at the same elevation.

The same type of instruments shall be used for control of utilities as for process control.

Instruments requiring external bleeds, sealing fluids or heating shall be avoided as much as possible.

Sealant material should be lactated F 202 or equivalent. The use of Teflon is forbidden.

Switches are forbidden. Threshold function shall be based on analog signals from transmitter. The thresholdfunction shall be realised inside PCS or PSS.

This shall be the rule as far as the emergency shut-down of a machine or process unit is concerned. Inspecific cases, switches could be used subject to COMPANYs authorisation.

The choice of control loop component locations shall be made in view of facilitating installation andmaintenance.

COMPANYs minimum requirements concerning instrument accessibility are given in section 6.

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5 Process Units Information

The following guidelines shall be followed when issuing hook-up drawings

Refer to the project document Ref. [14] instrument Hook-up Standards.

Care shall be taken to keep the variety of instruments to a minimum and to procure equipment offering thebest guarantees in terms of standardisation and Iocal maintenance.

Instrument technologies listed here below are the most common ones so this list is not exhaustive. Othertypes of instruments could be used according to the interest or context of the project.

5.1 Flow Instruments

5.1.1 General

As a general rule flow shall be measured, where possible, from orifice plate differential pressure.

VORTEX flow-meter may be used where turn down ratio is required and would necessitate several orificeplates to cover the whole range.

Rotameters shall be used for local indication only.

Other type of flow measuring shall be used only for very specific cases, and then only with COMPANYsapproval.

Sizing and design of process orifice plates shall be in accordance with ISO 5167 and 5168, unless specifiedotherwise by COMPANY. .

Bracketed values shall be used, unless otherwise required, giving 0.5% additional uncertainty.

Beta ratio limits for orifice plate shall be between 0.20 to 0.70.

Where compressible fluids are metered using a differential producing device, the selected differential shall

preferably not exceed 36 % of the upstream static absolute pressure. .

Selected differential range shall preferably be 0 to 250 mbar. Other ranges 0-125, 0-500 or 0-625 mbar maybe used if required by process conditions. Where pressure drops are a critical factor a lower range shall beconsidered.

In general, type 316 stainless steel paddle type orifice plates shall be provided.

Where the nature of the fluid is such as to require a higher alloy, or other material, it shall be consistent withthe line specification.

Orifice flange taps shall generally be used.

Orientation shall generally be horizontal. Where space limitations dictate, orientation of 45 up or down maybe considered.

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Mercury filled manometers shall not be used under any circumstances.

Measuring cells shall be able to withstand pressure up to the body rating in either direction and full vacuum.

The material used shall be in accordance with the piping specification but will be SS 316 as minimum.

Orifice plates shall be installed in horizontal lines; waivers may be granted for their mounting on vertical lineswith COMPANYs authorisation. Minimum straight sections shall be provided in accordance with API 550,CONTRACTOR shall increase the upstream straight sections wherever possible.

Transmitters shall be installed as close as possible to the taps.

When two transmitters are connected to the same orifice plate, each ones may be individually isolated bymeans of a compact block manifold.

The use of standards for the mounting of liquid flowmeters above taps and of gas flowmeters below tapsshall require prior authorisation from COMPANY.

5.1.2 Gas Flow

Instruments mounted horizontally with horizontal taps: this is the preferred installation.

Orifice plate mounted vertically with horizontal taps on the same side.

In vertical lines, the flow direction shall be downward.

Instrument mounted above the orifice plate: taps vertical or 45 up may be considered.

Impulse piping shall be given a slope of at least 15 % and its low points shall be provided with valves to drainthe condensates in the exceptional case of mounting below the orifice plate.

5.1.3 Liquid Flow

Instrument mounted horizontally with horizontal taps: this is the preferred mounting.

Orifice plate mounted vertically with horizontal taps on the same side.

In vertical lines, the flow direction shall be upward.

Instrument mounted below the orifice plate, taps 45 down may be considered.

Impulse piping shall be sloping 15 % towards the transmitter.

5.1.4 Use of Hook-Up Drawings

5.1.4.1 Short Mounting (Short Impulse Lines) used mainly for local indicators

It consists in mounting near the isolation valves.

However, accessibility precautions must be strictly observed.

5.1.4.1.1 Long Mounting (Long Impulse Line) for pressure transmitters and other instruments.

This shall be used only when the general accessibility rules preclude general mounting even after modifyingthe piping layout to enable access.

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5.1.4.1.2 Mounting Accessories

Mounting accessories shall be according to the selection criteria of instrument piping class.

The use of tubing (OD dimension), manifold blocks and double ferrule compression fitting are selected forthe project. Tubing and fittings to be imperial size.

5.1.5 Other Flow Measuring Devices

5.1.5.1 Meters

Installation shall be according to Manufacturers instructions.

Where electrical lines are involved, cable routing shall avoid risks of interference.

5.1.5.2 Magnetic Flowmeters

Magnetic flowmeters shall be provided with an earth ground.

In cases where the amplifier is separated from the coils, electrical power shall be provided from the coils, tothe amplifier.

5.1.5.3 Rotameters

Rotameters shall be installed on vertical pipes with upward flow.

On process lines, they shall be located on a by-pass to the main line with:

Two full-flow block valves having the same diameter as the rotameter,

One full-flow bypass valve on the main line.

If a control valve is provided, it shall generally replace the downstream block valve for liquid service and theupstream valve for gas service.

Rotameters shall be installed after flushing the lines.

Line proving shall be performed with the rotameter installed only if this one is all-metal.

5.1.5.4 Specific Metering (Fiscal, Turbine, Ultrasonic, Etc...)Specific rules are detailed in the relevant metering specifications.

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5.2 Level Instruments

5.2.1 General

For butane or pentane process streams displacement transmitters shall be used.

Differential pressure transmitters shall, in general, be preferred over displacement transmitters for otherstreams. The reference leg will preferably be kept dry.

The external cages for displacement type instruments shall be the manufacturers standard. External cageinstruments shall have a plugged vent, and drain connection.

When internally mounted displacer units are required, the minimum mounting flange diameter shall be 4inches. Stilling wells shall be provided in the vessel for these applications.

Vessel shall, in general, be suitable for side / bottom displacers connections. Where side / bottomconnections can not be installed side / side can be considered. Standard lengths used are limited to 14, 32,48 and 60. Other lengths may be considered subject to COMPANYs approval.

A stand pipe shall be used when:

There are two or more instrument levels and when the vessel rating is > 600 #,

There are three or more instrument levels and when the vessel rating is < 600 #,

However taps for shut-down level sensors shall always be dedicated and located on the vessel.

When Dp Flush is used connection on vessel shall be 4 flange.

Individual isolation and cleaning of instruments shall be possible in all cases.

In the case of an interface, instrument levels shall be installed such as to ensure permanent flood of theconnections. Each shall be independently mounted to the vessel, without a standpipe.

The lower level tap shall not be made in the bottom of the vessel. When a bottom tap cannot be avoided, theinserted pipe shall be made to enter 50 mm into the vessel.

Radiation fins shall be specified in accordance with standard manufacturers recommendations.

Where slurries or other difficult services are required, flange mounted type differential pressure transmittersmay be used for level transmitters.

Non intrusive methods may be considered where appropriate.

Ball float level instruments shall be used only for ON-OFF service or for actuation of electrical equipment.

Hydrostatic head bubbler type level instruments shall not be used.

Float and cable (automatic) tank indicators shall, in general, be used on storage tanks. Normally they shouldbe installed in a stilling well.

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5.2.2 Pressure transmitter

The high pressure side shall be connected to the lower tap.

The low pressure side shall be vented to the atmosphere if the vessel is not under pressure. Otherwise, itshall be connected to the upper tap. The instrument shall be located as a rule at the level of the lower tap.

Unless specific process requirements take priority, full bore valves shall be installed to allow removal of thedirectly flange mounted type transmitter.

5.2.3 Torque Tube transmitter

Preferred mounting shall be bottom-side. Where this is not possible side-side and top-side mountings areauthorised.

A stilling well shall be provided for instruments with internal float.

Mounting shall include a drain valve.

Drains for hydrocarbons or hazardous liquids shall be connected to a drain network.

5.2.4 Level gauge glasses

Liquid gauge glasses shall be used for local level measurement.

Tubular type gauge glasses shall be used only where approved by COMPANY.

Reflex type gauge glasses shall be used on clean, non-viscous liquids.

Thru-vision type gauge glasses shall be used on other liquids, for interface service, and for applicationsrequiring mica or other type shields Mica shields shall be used on steam and corrosive services

Straight flow valves shall be installed immediately close to the equipment (one for each level leg).

Union-type couplings between the level gauge and the gauge shut-off valves (which allow gauge orientation)shall be made of the same material as the gauge body.

All gauges shall be fitted with safety shut-off balls and shut-off valves with excess flow protection on top andbottom connections. Shut-off valves shall be quick acting.

Gauge glasses shall be selected from size type 9 and the maximum coverage, with a single gauge shall be 5sections.

Where greater coverage is required, multiple gauge glasses using either stand-pipes or independent vesselconnections shall be used with an over lap of at least of 50 mm.

Transparent type gauge glasses shall have fluorescent type or other illuminators suitable for areaclassification.

Magnetic type gauge glasses may be used subject to COMPANYs authorisation.

For services below minus 45 C, the level gauge shall generally be transparent type with illuminators andfrost extensions.

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Top and bottom fluid line connections shall be provided to enable better orientation. All other types ofconnections shall require justification in terms of special mounting requirements. The gauge glass shall beoriented to ensure visibility by the operators.

5.2.5 Level Switches

This type of instrument is not recommended and shall be avoided. It may be used only under COMPANYsauthorisation.

Internal mounting of the float shall be adopted only on an exceptional basis. In which case, a 4 horizontalflange shall be used for the location of the switch on the top of the vessel. A stilling well shall be provided.

Bottle-type level switches shall be mounted laterally (bottom-side connections), 1 flange type.

Mounting shall include a drain valve.

Drains for hydrocarbons or hazardous liquids shall be connected to a drain network.

5.2.6 Nucleonic Level Gauges

Installation of gauges shall be installed in accordance with Manufacturers recommendations.

Installation of gauges shall be submitted to COMPANY approval.

5.3 Pressure instruments

5.3.1 Pressure and Differential Pressure transmitter

Pressure transmitter ranges shall be selected such that normal operating pressure is within 50% to 80 % ofcalibrated range.

Standard over-range protection shall be specified and at least 3 times of the maximum scale. Instrumentsexposed to vacuum shall have under-range protection to full vacuum.

Pressure and differential pressure transmitters shall be with diaphragm or bellow type sensing elements.They shall have stainless steel wetted parts unless process fluid requires other material.

Both body and element material shall be ANS1 316 as a minimum standard.

5.3.2 Pressure switches:


Switches shall be enclosed in stainless steel housings rated to IP 65 with hermetically sealed contacts.

Switches shall have double pole changeover contacts rated at least 1A / 24V DC.

5.3.3 Pressure gauges

These shall normally be Bourdon tube type.

Where the nature of the fluid is such as to require a higher alloy or other metal, the primary element, materialshall be consistent with the piping or equipment specification.

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Where Bourdon tube gauges cannot satisfy range requirements, other standard applicable elements shallbe used.

For YSP the number of standard ranges shall be minimised and selected according to standardmanufacturer.

The range of pressure gauges will be selected so that the normal pressure will be within 50 to 80% ofcalibrated range and shall be capable of withstanding over-pressures up to the prevailing design pressure orrelieving pressure of the equipment. When this is not possible gauge protection devices may be employed.

Diaphragm seals may be fitted to pressure instruments in corrosive, viscous or services containing solids.

Pressure gauges shall normally have a diameter of 100 mm. They shall have, as a minimum, all wetted partsand internals of stainless steel, and the external shall be filled with Glycerine.

Manometers may be furnished where required for low pressure or absolute pressure measurements.Mercury filled manometers shall not be used.

Pressure gauges shall be furnished with pulsation dampers for pulsating services.

5.3.4 Pressures Taps

Pressure taps shall be made with 3/4 piping (2 for pipeline).

Different dimensions may be used on an exceptional basis as required for instruments with separatingdiaphragms, for example, or for analyser sampler circuits.

No pressure taps shall be made in turbulence zones (elbows, reducers, etc).

Except where required by the process or in the case of piping of 1500 #, two instruments shall never beconnected to the same tap.

Taps shall be perpendicular to the axis of the piping

Position shall be horizontal in vertical lines

Vertical and near the top in horizontal gas service lines

Horizontal in horizontal liquid or steam services lines.

5.3.5 Mounting

Short mounting shall be the preferred mounting, based on the same general rules as stated for flowmeasurements. A decompression valve or plus shall be systematically provided.

5.4 Temperature Instruments

5.4.1 Temperature transmitter

Temperature measurements shall be generally taken with RTD in a thermowell and associated with a 4-20

mA transmitter smart type.

Temperature transmitters will be integrally head mounted with thermowell.

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Use of thermocouples or separate-amplifier RTDs shall be restricted to machines and heaters.

The heaters are to be fitted with skin temperature sensors. These thermocouples shall be fitted withtransmitters local to the heater to minimise the use of compensated cable and to use only 4-20 mA analoginput cards on the PCS/ESD systems.

RTDs and thermocouples shall be 6mm OD ground insulated type unless otherwise required

RTD Ceramic type sheaths may be provided for gas phase measurement in fire-box and flue gas areas atheater, boilers, furnaces, stacks and large vessels which operate at 450 C and higher.

Resistance probe RTD will be class A tolerance unless otherwise stated and shall be the preferred methodof temperature measurement, for process temperatures up to 500 C

Resistance probe RTD shall have a resistance of 100 at 0 C, 3 wires type.

Heaters to be fitted with skin thermocouples. These thermocouples shall be fitted with transmitters local tothe heater to minimise the use of compensated cable and to use only 4-20 mA analog input cards on thePCS/ESD systems.

5.4.2 Thermometer

Local indicating thermometers shall be bimetallic dial type, with a diameter of 100 mm, every angle type.

Bi-metallic temperature indicators shall be supplied as complete assemblies comprising:

indicator, extension nipple and thermowell.

Scale graduations, zero adjustment and over-range protection shall be Suppliers standard. Accuracy shallbe within 1 % of span.

Ranges shall be selected such that the normal operating temperature indication is approximately within 50%,80% of the calibrated range.

Scales shall be direct reading and standard ranges shall be as selected.

Bi-metallic thermometers in service where vibration may be expected shall be either silicone filled or haveother internal dampening means.

Where specified, or where remote indication is required, thermometers of the filled capillary type shall beused. (Mercury must not be used). Where capillary tubes are used, care should be taken to ensure that theadequate support and protections provided.

5.4.3 Thermowell

Thermowell type shall be one piece thermowell, bored from one piece solid bar stock or forgings, and shallinclude a retaining flange. Tapered thermowells with round tip shall be selected.

The thermowell standard material is SS 316L. Monel is recommended for seawater services.

The cover flange and the thermowell shall always meet the relevant Piping Class material requirements for

material selection and dimension.

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Thermowells shall be made in conformity with the ASME PTC 19.3 calculations. The Supplier shall supplyfrequency and stress analysis calculations.

CONTRACTOR shall perform pre-sizing of the well.

Test wells for general use shall be provided with screwed plugs permanently attached by stainless steelchain.

Immersion length: the tip of the thermowell shall be located within the second third of the flow line diameter.

Thermowells shall be connected to the piping via a 1 1/2 (2 on vessels) Welding Neck flange tube,depending of the Piping Class material and stress analysis results of the thermowells

For thermowell installation in pipes with a diameter of less than 4, a widening of the pipe to 4 shall beprovided ; the coupling shall be welded to centre the sensing part of the well in the process line.

On horizontal lines, the thermowell shall be connected to the top part of the pipe.

For thermowell installation on vertical line with a diameter of less than 3, a widening of the pipe to 3 shallbe provided.

The thermowell shall be installed preferably in straight runs of pipe or, when it is not possible, in an elbowwith flow opposing the thermowell.

Couplings or pipes located before exchanger outlet flanges shall not be used as permanent measuring

points.

An exception will be made in the case of superposed exchangers.

For thermowells longer than 500 mm, an engineering note shall be provided documenting the wells bendingstrength and, where relevant, its buckling strength.

For installation convenience, the thermowells shall be guided or a shorter thermowells shall be selected byagreement with COMPANY.

Different thermowell standards may be adopted in special cases, such as:

Lens rings mounting on wellheads,

Mounting with radiation-proofing for high-vacuum processes.

5.4.4 Temperature Switches


Switches will be enclosed in stainless steel housings rated to lP65 hermetically sealed. Switches shall havedouble pole change over contacts rated at least 1amp at 24 VDC.

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5.5 Miscellaneous Measuring Instruments

5.5.1 Tachometers

Local tachometers shall be mounted on the machines or on the field panel and be visible by the operatoroperating the start-up panel.

They shall be easy to remove while machine is running.

These instruments shall be pulsed - output electronic type.

5.5.2 Vibrations

Electric output, enabling measurement of amplitude and frequency of vibrations. Instruments shall beinstallable and removable on-line.

Vibration sensors are usually included in the mechanical vendor scope.

Labelled locating points (couplings, spoffacings, etc) are provided on bearing bodies for makingmeasurements of vertical and horizontal vibrations perpendicular to the axis: sensors without contact shallbe installed in the bearings and their outputs routed to instruments at the remote control panel.

Location of measuring points: sensors without contact shall be mounted radially on each bearing. Twosensors should be provided at right angles in each radial plane.

The exact location where the measurement is made shall be marked on the machine itself.

CONTRACTOR shall carefully select the locations for vibration sensors. The shaft surface should be smoothand free from scratches, oxidation, eccentricities, diameter variations, threads and so on.

The vibration sensor shall be adapted to the shafts metal and finishing or surface treatment.

Sufficient clearance shall be provided to ensure that sensor detects only movements of the shaft andoperates in its linear range.

The sensor shall not be mounted on a part of the shaft susceptible to thermal expansion.

Cables shall be routed to avoid excessive temperature exposure. This point is critical where gas turbines areconcerned.

Sensors shall be spaced sufficiently apart to avoid crosstalk.

Penetrations of bearing boxes shall be through the bottom half to enable their opening without damaging thecable.

The sensing end of the sensor shall be maintained at a suitable distance from any metal parts, which mightdistort the measurement. Its support shall be bevelled to allow a lateral clearance equal to the diameter ofthe probe.

The sensor mounting bracket shall be stiff and secured by two bolts.

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5.5.3 Displacement Or Axial Thrust

Axial position sensors shall be placed in the thrust bearing and their output signals shall be routed toinstruments at the remote control panel.

Axial thrust sensors shall be installed in accordance with API 670.

5.6 Control Valves

Refer to the project document Ref. [6] Control valve specification.

The valve characteristics shall be specified so as to obtain a linear valve characteristic over the operatingrange. To achieve this, the characteristic shall normally be Linear when the major part of the energy loss in a

valv