A-1-GEN-IN-PH-0004

PTTEP ARTHIT FIELD DEVELOPMENT CENTRAL FACILITIES INSTRUMENT REQUIREMENTS FOR PACKAGED EQUIPMENT A-1-GEN-IN-PH-0004

CONTRACT NO . A-TPD 03-0043 This cover page is a record of all revisions of the standard/specification identified above by number and title. All previous cover pages are hereby superseded and are to be destroyed.

B1 A1 R1

15/7/04 27/4/04 14/4/04

Approved For Design Issued For Approval Issued for IDC

MMJ VA VA

VA SB SB

VA SB SB

BMK BMK BMK

Rev. No.

Date

Purpose of Issue

Prepared By

Checked By

Discipline Approval

Project Approval

SW

Client Approval

PTTEP Arthit Field Development Central Facilities

Doc. No. A-1-GEN-IN-PH-0004

Rev. B1

INSTRUMENT REQUIREMENTS FOR PACKAGED EQUIPMENT Page 2 of 49

TABLE OF CONTENTS 1.0GENERAL

3

2.0 Flow Instruments

10

3.0 Pressure Instruments

16

4.0Level Instruments

19

5.0Temperature Instruments

21

6.0Control Valves

26

7.0Control Panels

40

8.0General Electrical Requirements

44

9.0Additional Requirements

47



Rev. B1


1.0

GENERAL 1.1 and Intent

Scope

This specification prescribes a basis for the consistent application of instruments and controls to mechanical packaged equipment. It shall be used by the Vendor’s Mechanical and Control Systems/Instrumentation disciplines for the design, supply and application of instruments and controls. It is the intent that all instruments furnished with mechanical packaged equipment meet the requirements of this specification. With Company’s prior concurrence, the use of the Packager’s standard instruments and materials will be permitted. Where compliance with this specification causes a deviation from that normally supplied in the standard package, the impact to supply such materials shall be stated in the proposal. It is the purpose of this specification to provide for the following. • To ensure that instrumentation provided by equipment suppliers conforms to the control systems and instrumentation design philosophy of the plant. • To reduce the number of different instrument manufacturers and types of instruments in the plant to a minimum. • To ensure that information on instrument and control items is readily available to all of the Purchaser’s design departments and Performing Agents. • To establish a minimum acceptable quality level for instruments and controls. 1.2Project overview PTT Exploration and Production Public Company Limited, (PTTEP), in partnership with Unocal and MOECO, intend to develop and produce gas and condensate from an offshore concession, identified as the Arthit Field. The Arthit Field is comprised of concession block numbers 14A, 15A and 16A in the Gulf of Thailand. This project is a part of the Arthit Field Development Project and comprises the Arthit Central Process Platform, (APP), the bridge connected Arthit Quarters Platform, (AQP), and the bridge connected Arthit Flare Platform, (AFP). Definitions COMPANY

refers to PTT Exploration and Public Production Company Limited (PTTEP)

PURCHASER

refers to PTTEP, or PTTEP’s Performing Agent for purchasing

VENDOR

refers to the Supplier of equipment, instruments, controls, materials, software, and services as detailed in the relevant data sheets/specifications.



Rev. B1


1.3

Codes and Industry Standards All work and equipment and services provided by the Vendor shall comply with the following codes where applicable. The referenced standards and codes shall not be interpreted to limit the scope of supply and work referenced in the purchase order. The latest editions of the listed codes and standards shall govern the work.

1.3.1

API (American Petroleum Institute) MPMS 12.2 MPMS 14.3

RP 14C RP 14F

RP 14G RP 520 RP 521 RP 526 RP 527 RP 551 RP 552 RP 554 RP 555 RP 574 SPEC 6D STD 598 STD 607 STD 2000 STD 2530 6FA

1.3.2

ASME (American Society of Mechanical Engineers) Sect. VIII, B 16.36 B 16.5 B16.104

1.3.3

Manual of Petroleum Measurement Standards, Chapter 12, Section 2, “Calculation of Liquid Petroleum Quantities Measured By Turbine or Displacement Meters” Manual of Petroleum Measurement Standards, Chapter 14, Section 3, “Orifice Metering of Natural Gas and other Related Hydrocarbon Fluids” (AGA Report No. 3; ANSI/API 2530) Analysis, Design, Installation and Testing of Basic Surface Safety Systems on Offshore Production Platforms Recommended Practice for Design and Installation of Electrical Systems for Fixed and Floating Offshore Petroleum Facilities for Unclassified and Class I, Division 1 and Division 2 Locations Recommended Practice for Fire prevention and Control on Open Type Offshore Production Platforms “Sizing, Selection, and Installation of Pressure-Relieving Devices in Refineries, Parts I and II” “Guide for Pressure-Relieving and Depressurizing Systems” “Flanged Steel Pressure Relief Valves” “Seat Tightness of Pressure Relief Valves” “Process Measurement Instrumentation” “Transmission Systems” “Process Instrumentation and Control” “Process Analyzers” “Inspection Practices for Piping System Components” Pipe line Valves (Gate, Plug, Ball and Check Valves) “Valve Inspection and Testing” “Fire Test for Soft-Seated Quarter-Turn Valves” “Venting Atmospheric and Low-Pressure Storage Tanks, Non-Refrigerated and Refrigerated” Orifice Metering of Natural Gas Specification for Fire Test for Valves

ASME Boiler and Pressure Vessel Code, Section VIII Pressure Vessels, Division I “Rules for Construction of Pressure Vessel” Orifice Flanges Pipe Flanges & Flanged Fittings Valve Leakage Classification / FCI 70.2

IEC (International Electrotechnical Commission) IEC 60079

Electrical apparatus for explosive gas atmospheres



Rev. B1

INSTRUMENT REQUIREMENTS FOR PACKAGED EQUIPMENT Page 5 of 49 IEC 60331 IEC 60332 IEC 60529 IEC 60534-8 IEC 60751 IEC 60801-1 IEC 61000 IEC 61131 IEC 61508 IEC 61511

1.3.4

The Energy Institute IP Part-1 IP Part-15

1.3.5

S5.4 S20 RP31.1 S51.1 S75.11 S75.01 S75.25

Flange Mounted Sharp Orifice Plates for Flow Measurement Instrument Symbols and Identification Binary Logic Diagrams for Process Operations Graphic Symbols for Distributed Control/Shared Display Instrumentation, Logic and Computer Systems Instrument Loop Diagrams Specification Forms for Process Measurement and Control Instruments, Primary Elements and Control Valves Specification, Installation, and Calibration of Turbine Flow meters Process Instrumentation Terminology Control Valve Flow Characteristics and Rangeability Flow equations for sizing Control valves Measuring Process Control Valve Response

ISO (International Standards Organization) ISO 5167 ISO 1461

1.3.7

Institute of Petroleum Model Code of Safe Practice in the Petroleum Industry – Electrical Safety Code Institute of Petroleum Model Code of Safe Practice in the Petroleum Industry – Area Classification Code

ISA (Instrument Society of America) RP3.2 S5.1 S5.2 S5.3

1.3.6

Fire resisting characteristics of electric cables Tests on cables under fire conditions Part-1: test on a single vertical insulated wire or cables Part-3: tests on bunched wires or cables Degrees of protection provided for enclosures (IP code) Industrial-process control valves. Part 8: Noise considerations Industrial Platinum resistance Thermometer sensors Electromagnetic compatibility for industrial-process measurement and control equipment Electromagnetic compatibility (EMC) Programmable Controllers (part 1 to 8) Functional Safety of Electrical/Electronic/Programmable Electronic Safety-related Systems Functional Safety: Safety Instrumented Systems for the Process Industry Sector

Measurement of fluid flow by means of Orifice Plates, Nozzles & Venturi Tubes Inserted in Circular Cross Section Conduits Running Full Hot Dip Galvanized Coatings on Iron and steel articlesSpecification and test Materials

AGA (American Gas Association) Report No 3 Report No 8

Orifice metering of natural gas and other related hydrocarbon fluids Compressibility Factors of Natural gas and other Related Hydrocarbon Fluids



Rev. B1


1.3.8

NACE (National Association of Corrosion Engineers) MR0175

1.4

Sulfide Stress Cracking Resistant Metallic Materials for Oilfield Equipment”

Company Specifications and Documents The following Company documents shall be considered a part of the design basis. The latest revision shall apply. AGS-8 AGS-9 AGS-11 AGS-12 AGS-18 AGS-23 AGS-53 A-1-GEN-QC-PR-0004

1.5

Piping Materials Installation of Instruments & Controls Electrical Work Electrical Requirements for Mechanical Equipment Site Conditions and Climate Design of Instrumentation Electrical and Instrument Cables Equipment, Line and E&I tagging procedure

Packaged

Abbreviations APP

Arthit Central Processing Platform

AQP

Arthit Quarters Platform

ATEX

Atmosphere Explosive

AWP

Arthit Wellhead Platform

CCR

Central Control Room

CENELEC

European Committee for Electrotechnical Standardization

DC

Direct Current

ESD

Emergency Shutdown

F&G

Fire & Gas

FSO

Floating Storage and Offloading Facility

IEC

International Electrotechnical Commission

IP

Ingress Protection

LER

Local Equipment Room

mmscfd

Million Standard Cubic Feet Per Day

MTO

Material Take-Off

P&ID

Piping & Instrumentation Diagrams

PCS

Process Control System

PLC

Programmable Logic Controller

PTT

Petroleum Authority of Thailand, Public Company Limited

PTTEP

Petroleum Authority of Thailand Exploration and Production Public Company Limited

SIS

Safety Instrumented System

VDR

Vendor Data Requirements



Rev. B1


1.6Conflicts In the case of a conflict between the requirements of this specification, and other referenced codes, standards, or specifications, the following order shall prevail: • Regulations

Local

• Sheets

Data

• specification

This

• d Company specifications

Reference

• al codes and standards

Internation

Where conflicting requirements are perceived or noted, these shall be brought to the attention of the Company in writing. Conflicts between specifications shall be resolved in accordance with the terms of the Contract. Applicable International standards shall be of latest editions as of 08 March 2004. 1.7General Requirements and Information Instruments and instrument-electrical materials shall be furnished in accordance with the Company approved list of Manufacturers. The use of Mercury and Asbestos is generally not permitted. The use of mercury wetted switches must be approved by Company. Design, material, equipment, and installation shall meet the specified passive electrical area classification without purging. Company/Purchaser will provide area classification requirements. Within two weeks of the purchase award, the Vendor shall provide a preliminary estimate of interconnecting cabling/wiring by type, size, and number of conductors. Company/Purchaser acceptance shall not relieve Vendor of the responsibility of furnishing functionally safe equipment that meets all referenced and applicable safety requirements. Unless otherwise stated, a Company/Purchaser/Vendor coordination meeting is required to define, review, and accept operational issues and programming approach. Instrument ranges, pressure ratings, and materials of construction shall be based on specified fluid properties and data, operating conditions, and design basis. Vendor shall provide an interface block diagram showing battery limits of his scope of supply and installation work.



Rev. B1


Vendor shall be responsible for all cable routing within the skid. Instrument cables will be terminated in a dedicated junction box for further Interconnection to the main control system (by Company/purchaser). Analog signals, (including Fieldbus), and Discrete, (on/off, digital), signals and power cables shall be terminated in separate junction boxes. Vendor shall submit an Instrument location layout drawing showing the location of all instruments, junction boxes, local control panels, cable routing, and tubing routing. Where tubing interfaces are required outside the package skid, Vendor shall terminate such tubing on bulkhead plates to enable Company/Purchaser to pickup the interface. Vendor shall provide a tubing interface drawing showing the bulkhead plates and location with in the package. Control instruments and valves shall be designed and configured such that the failure mode is to a safe process condition. The supply and installation of certain instrumentation by others, (if required), in no way lessons Vendor’s responsibility to provide the basic design for instrumentation. When required, the Vendor shall supply a P&ID in accordance to Purchaser’s format and ISA Standard S5.1. The Vendor shall furnish sizing calculations for all control valves, flow measurement, and pressure relieving devices. Instrument design shall be per AGS-23, latest revision. Instruments that require field installation and items that were removed and shipped loose shall be identified on the drawings, packing lists, and on the item itself. The “shipped loose items list” shall be issued to Company/Purchaser at the time of detailed engineering. Instrument data sheets in ISA format shall be provided for each instrument within the scope of supply. Instruments shall be supplied in or covered with sealed, heavy plastic bags containing desiccant material during shipment and be adequately protected from mechanical damage. Pressure and temperature ratings of instruments shall be the same as the vessel or piping to which they are attached. All Instruments shall be installed in accordance with of AGS-9. Materials for instrument construction and mounting shall be compatible with the site conditions listed in AGS-18 and process wetted parts shall be compatible with the process fluid.



Rev. B1


The requirements listed herein are additional requirements to AGS-23. This document should be read in conjunction with AGS-23 and all requirements not here but in AGS-23 shall be met. All electronic transmitters shall be suitable for Zone 1, GRIIA, T3 atmosphere and shall be certified EExd to CENELAC standards by BASEEFA or equal. 1.8Main Control System Interface Arthit Central Facility will have an integrated automation system consisting of a Process Control System and a Safety Instrumented System. The CCR will be located on the AQP and there will be a LER on the APP to locate facility control equipment and selected package unit control panels. Packages that are directly interfaced with the Main control system shall be hard wired from the package limit junction boxes. Packages that have PLC control will have all the Instrumentation connected to the package PLC. Exceptions may be required by the Company. Where exceptions exist, they will be shown on P&ID's. The Package PLC will be connected to the facility’s Control System in accordance with the complexity and control strategy adopted for that particular package.

1.9 Measurement

Units

of

Units of measurement shall be Metric unless stated otherwise. English unit equivalents should be shown in parenthesis on documentation. 1.10 Environmental Conditions Refer to AGS-18 for detailed information. • sea level

Altitude:

• Ambient temp: 36 deg C (96.8 deg F)

Maximum

• Ambient temp: 22 deg C (71.6 deg F)

Minimum

• Humidity: 100%

Avg. Max.

• Humidity: 50%

Avg.

• e: Salty and corrosive marine environment

Atmospher

Min.



Rev. B1


• LER/CCR will be air-conditioned and normal temperature will be 21-24 deg C (70-75 deg F) with a relative humidity of 50%. All Instrumentation equipment in the LER/CCR will be designed for 40 deg C (104 deg F) and relative humidity of 100% 2.0

FLOW INSTRUMENTS 2.1General The selection of flow instrument type shall be made based upon normal industry practice considering the process conditions and the desired rangeability and accuracy. Where selection has been made and is called out on P&ID's or in specifications, no change should be considered without Company approval. 2.2 Meters

Turbine

Turbine meters when used shall be installed in horizontal lines with an upstream strainer in accordance with API Manual of Petroleum Measurement Standards Chapter 5. Accuracy of turbine meter (inclusive of accuracy of the converter) shall be 0.5% of the flow range. Repeatability shall be 0.03% of the reading. Turbine meters shall include a local totalizer with 8 digits. The totalizer shall be non resettable, and it shall be powered by an internal battery if required. Care must be taken to ensure that there is always a positive head of liquid upstream equivalent to at least twice the pressure through the meter. Disturbances in the flow pattern caused by offset between upstream piping and meter flanges or gasket protrusion into the pipe can seriously affect the performance of the turbine meter and extra precautions to be taken in the design of the installation to eliminate these potential problems. Turbine meters must be calibrated over the full process range to confirm the meter performance and establish the initial K factor for flow computation. Turbine meters shall be protected against over speed, reverse flow and shocks. The guidance provided in ISA RP 31.1 shall be followed for turbine meter installations. Turbine meters shall be installed so they are always in single phase flow, liquid full in liquid applications, and liquid free in gas applications. The installation setup shall avoid creating a pressure drop condition for the fluid to flash in meter. Turbine meters shall be marked to indicate proper flow direction. In-line type turbine meters 1.0 inches and above shall be flanged. A strainer shall be installed upstream of turbine meter system. Dual strainers shall be provided if the process flow cannot be interrupted for maintenance. Strainers



Rev. B1


shall be installed far enough upstream to prevent the distortion of flow profile at the turbine meter. Liquid turbine meters shall be installed in accordance with API MPMS, Chapters 5 and 6, for high accuracy applications. In-line gas turbine meters shall have rotor module removable from top of meter through a special flange or through bore of meter for meters larger than 3 inches. 2.3Orifice Meter Square edge orifice plates shall be used. The following minimum information shall be stamped or etched on the upstream side of the handle: • plate tag number

orifice

• type

material

• drain hole size

vent

or

• side

inlet

flow

•

bore

• in inches and ASME pressure rating

flange size

Orifice plates shall be fabricated to meet ANSI 2530/API 14.3/AGA-3/GPA-8185. Vent or drain holes in orifice plates shall only be used if specified in the datasheet. Flange type and material shall conform to piping specifications. Orifice flanges shall be rated at a minimum of ASME Class 300 and conform to ASME B16.36 and ANSI 2530/API 14.3/AGA-3/GPA-8185. Orifice “flange taps” shall be used for line sizes 2 inches and larger unless otherwise approved by Company. Corner taps shall be used for line sizes less than 2 inches. Orifice flange tap connections shall be ½ inch when used in ASME Class 600 service and below unless otherwise required by piping specifications. Orifice flange tap connections shall be ¾ inch when used in ASME Class 900 service unless otherwise required by piping specifications. Connection type (threaded or socketweld) shall be as per piping specifications. Other taps, when used, shall be per piping specifications. Piping design for orifice runs shall conform to the following:



Rev. B1


Orifice meters shall be installed in horizontal runs to minimize measurement inaccuracies. Vertical orifice runs shall be used only with Owner’s approval. Orifice meter tap locations shall be as follows: • For “flange tap” designated orifice meters, the taps shall be located at 1 inch upstream and 1 inch downstream from the orifice plate face including gasket thickness. • For “pipe tap” designated orifice meters, the taps shall be located 2-1/2 internal pipe diameters upstream and 8 internal pipe diameters downstream of the orifice plate face. Meter tube pipe and orifice flanges internal dimensional tolerances shall be in accordance with ANSI 2530/API 14.3/AGA-3/GPA-8185. Straight run piping before and after an orifice plate flow element shall be as per ANSI 2530/API 14.3/AGA-3/GPA-8185. If the straight length requirements of ANSI2530/AGA 3 cannot be met due to piping layout restrictions, than as a minimum 10D upstream and 5D down stream shall be provided



Rev. B1


Table 1

NOTES for Table 1: (1)

Any flow conditioner shall be installed in the straight length between the primary element and the upstream disturbance, or the fitting closest to the element. The installation location shall be per applicable standard.

(2)

Interpolate pipe diameters for intermediate beta ratios.

(3)

This information is based on ANSI 2530 / API 14.3

(4)

With two elbow separation greater than 10 diameters use single elbow lengths.

(5)

With two elbow separation greater than 10 diameters use two elbows in same plane lengths.



Rev. B1


2.4Flow Nozzle Flow nozzles shall be designed to bolt between flanges unless otherwise required by service application and piping specifications. In high pressure (1000 psig or higher) applications, the flow nozzle shall be welded directly into the pipe. Tap connections shall be installed 1 inside pipe diameter upstream and ½ inside pipe diameter downstream in accordance with ASME-MFC-3M. Minimum straight run pipe length requirements shall conform to Table 1. Flow nozzles shall be 316 SS unless otherwise required by process service or piping specifications. 2.5 (Classical and Proprietary Designs)

Venturi

Classical venturi shall be fabricated according to ASME MFC-3M specifications. Venturi meter materials and construction shall be compatible with the process fluid and applicable piping codes. Flow calculations for proprietary venturi meters shall be supplied by manufacturer. Minimum straight run pipe length requirements shall conform to ISO 5167 requirements. 2.6 Pitot Element

Averaging

Unless they are bi-directional, averaging Pitot tube elements shall be permanently marked to indicate proper installation position and flow direction. Averaging Pitot tubes shall be 316 SS unless otherwise required by process services. Minimum straight run pipe length requirements shall conform to manufacturer's recommended lengths as a minimum; however, longer lengths are preferred. For instruments with a removable element, the process valve shall have the proper inside diameter to allow passage of the element. This valve shall meet applicable piping specifications. Blow out prevention is required for removable elements. The manufacturer’s recommendations shall be followed and shall meet Company’s piping specifications. Extra heavy flow elements and/or double ended support shall be used in large diameter pipes or ducts or where high flow velocity may cause the element to deflect or vibrate. Manufacturer’s installation recommendations shall be followed.



Rev. B1


2.7 Orifice

Integral

Integral orifices shall be sized and installed in accordance with manufacturer's recommendations. Manufacturer shall supply meter sizing and flow calculations. Minimum straight run pipe length requirements shall conform to manufacturer's recommended lengths as a minimum; however, longer lengths are preferred. A strainer shall be required in dirty service to avoid plugging of the orifice. 2.8 Displacement Meter

Positive

Inlet and/or outlet ports shall be plainly marked to indicate proper flow direction. The meter shall be installed so that the fluid passing through the meter is in a single phase and the meter is liquid full. A strainer shall be installed upstream of the meter. Meters in line sizes 1-1/2 inches and above shall be flanged body style. 2.9 Flow Meter

Magnetic

Materials of construction shall be compatible with the process fluid. The liner material and liner thickness shall be chosen to meet the requirements of the chemical compatibility, abrasion resistance, temperature and pressure limitations. To avoid damage to the liners, spiral wound gasket shall not be used. Straight lengths of pipe upstream and downstream of the meter shall be provided as recommended by the manufacturer for the specific application. Magnetic flow meters shall be installed with piping designed in accordance with manufacturer’s recommendations. Magnetic flow meters shall be grounded in accordance with manufacturer's recommendations. Magnetic flow meters shall be installed so that the meter is always liquid full. The preferred installation is vertical with flow up. The meter factor data shall be supplied by the manufacturer. 2.10 Area Meter (Rotameter)

Variable

Rotameters shall be installed in a vertical position and piped per manufacturer’s recommendations. Rotameters shall be accessible for easy reading and for maintenance or repair.



Rev. B1


The capacity of the rotameter selected shall be such that normal flow rate falls in middle one-third of chart or scale range. For process flows, scales shall be graduated in percent units. Meter factor for maximum flow at 100% shall be engraved on scale. Glass tube meters shall only be used on air, inert gas and water at temperatures of 60Deg C or less and pressures 100 psig or less. Company’s approval is required for use of glass tube rotameter in other services. For purge meter applications, a check valve shall be installed on the outlet of the meter to prevent back flow. 2.11

Other Meters 2.11.1 Meter (Coriolis)

Mass

The meter shall be sized so the maximum full scale flow rate is in the upper third of the meter range unless pressure drop considerations require a larger size meter. 2.11.2 Meter (Thermal)

Mass

Use of thermal meters shall have Company’s approval. 2.11.3 (Transit Time & Doppler)

Ultrasonic

Use of ultrasonic meters shall have Company’s approval. 2.11.4 Shedding Meter

Vortex

Flow direction shall be permanently marked on the meter body. The vortex shedding meter internal inside diameter shall be matched as closely as possible to the adjoining process pipe inside diameter. Proper gasket sizing shall be followed to avoid protrusion into line. 3.0

PRESSURE INSTRUMENTS 3.1

General

Pressure Instruments shall be provided with diaphragm or chemical seal systems when installed in services involving the following fluids: • streams

Corrosive

• streams

Viscous



Rev. B1


• will subject the element to temperatures higher than 300 deg F

Fluids that

• streams

Toxic

Pulsation dampers shall be furnished as an integral part of all pressure transmitters and liquid filled pressure gages on the inlet and discharge of reciprocating pumps; on the suction and discharge of reciprocating compressors; and other pulsating services. Accuracy for transmitters shall be 0.075% of span or better.

3.2 Gauges

Pressure

Pressure gauges shall utilize standard ranges and shall be selected such that the normal operating pressure falls between 50% and 70% of the range. Process gauges shall have a 4.5 inch (minimum) face that provides for ease in reading. Accuracy of 1% of span or better. Gauge construction shall provide for ease of maintenance. Gauge savers shall be used when the operating pressure of the service to which the instrument is attached can rise above the maximum working pressure of the instrument. Liquid fill shall be used in vibrating service. 3.3 Transmitters

Pressure

Pressure transmitters shall be of the Smart type being either HART or Foundation Fieldbus depending upon the application. Purchaser will specify the type. The instrument manufacturer shall be the same as selected for the facility control system. Exceptions must be approved by the Company. Ranges for pressure instruments shall be approximately double the normal operating range. Suppressed ranges shall be used for transmitters in control loops where necessary to insure proper readability and control. 3.4 Differential Pressure Instruments 3.4.1

General

Differential Pressure transmitters shall be of the Smart type being either HART or Foundation Fieldbus depending upon the application. Purchaser will specify the type. The instrument manufacturer shall be the same as selected for the facility control system. Exceptions must be approved by the Company. Span calculations shall be based on the anticipated operating specific gravity of the process.



Rev. B1


DP instruments shall be fitted with five valve manifold for zeroing and in place calibration. The material of the manifold shall be minimum SS316 or to suit process as per relevant data sheet. DP based flow transmitters shall have local indicators with 0-100% scale. Square root extraction shall be accomplished in PCS. Indicators shall be capable of being configured in engineering units. 3.4.2

Level

Transmitters shall be mounted at or below the centerline of the high pressure nozzle (lower nozzle on vessel). 3.4.3 Diaphragm Seals The diaphragm seal fluid, seal leg fluid, or purge fluid shall be compatible with the process and ambient temperature extremes. Transmitters with remote diaphragm seals shall be mounted at or below the high pressure nozzle (lower vessel nozzle). Provisions shall be made for relieving pressure between the block valve and the diaphragm seal. Clean out or purge connections may be required on the process side of diaphragm seals in applications where plugging is likely. Capillary tubing seal legs shall be mechanically protected and adequately supported to prevent sagging. Remote diaphragm seals used in vacuum service applications shall be specifically designed for vacuum service by the manufacturer. Welded capillary connections shall be specified for vacuum applications. Fill fluid shall be rated for the maximum temperature and maximum vacuum conditions. Diaphragm seal capillary tubing lengths shall be designed to take into account routing requirements. Capillary tubing shall be manufacturer’s standard lengths. However, capillary lengths that are too long are undesirable so the Vendor shall choose the minimum standard length considering prudent capillary routing. Capillary lines shall be routed away and/or insulated if they pass by steam or high temperature heat transfer media jackets on a vessel or other high temperature sources. Capillary length of both seal legs shall be identical on a remote seal differential pressure transmitter. Remote diaphragm seals without block valves shall not be installed until the flush and pressure test of the vessel is complete.



Rev. B1


4.0

LEVEL INSTRUMENTS 4.1 Displacement Instruments Displacement type level instruments shall not be used for: • materials

viscous

• which require purging to prevent plugging and/or sticking

services

• services where there is condensation or vaporization of fluids in the chamber due to vessel-chamber temperature differences • which have agitated fluids

services

Displacer instruments shall not be used in services where the measurement exceeds 48 inches without Company approval. Displacement transmitters shall not be used in liquids that coat or build up deposits on the displacer and rod. Rotatable head shall be provided with displacer type instruments Displacer chambers shall have a Maximum Allowable Working Pressure (MAWP) equal to or greater than that of the vessel. All wetted parts (displacer element, hanger rod, torque tube or springs, and assembly components) shall be compatible with the process. For measuring liquid-liquid interface the displacer shall be completely submerged. For measuring liquid-liquid interface with standard displacers, the difference in specific gravity of the two liquids shall be greater than 0.1. The manufacturer shall be consulted for interface measurement. The displacer shall be freely suspended in the liquid (i.e., it shall not contact the bottom/sides or any buildup on the vessel or chamber). 4.2 Capacitance Instruments Capacitance level transmitters shall not be used if the liquid conductivity may change from non-conductive (less than 10 micro mho/cm) to conductive (greater than 10 micro mho/cm). A special probe with a separate electrode for signal return shall be used on nonmetallic or lined vessels.



Rev. B1


The probe shall be externally grounded to the vessel if PTFE tape or other pipe thread coatings are used. 4.3 Contact Instruments

Non-

Non-contact instrument types include ultrasonic, sonic, microwave, and radar technology. Use of non-contact instruments requires Company approval. When non-contact instruments are used for solids service, they shall be designed for that service. The manufacturer shall concur with the application and the installation. 4.4 Instruments

Nuclear

Nuclear source type level instruments shall only be used with Company’s approval. Nuclear instruments shall be installed and maintained in accordance with instructions of the instrument manufacturer and applicable local, state, and federal regulations. At the time of purchase, the vendor shall state in writing that they will dispose of the source after the instrument is removed from service. Company’s policy for installation, handling, and control of nuclear sources shall be followed. 4.5 Switches

Level

Level switches can be of Capacitance, RFI, Ultrasonic (contact), Nuclear, Ball Float, Displacer, and Thermal, Vibration, or Electromechanical types. Level switches that contain mercury shall not be used without Company approval. Provisions shall be made for testing and maintenance of level switches. Company approval is required for use in Safety Instrumented Systems. 4.6 Indication

Level

4.6.1 Gauges

Magnetic

Magnetic gauges shall not be used in dirty or plugging service. The float shall be designed for the range of process fluid specific gravity per the data set.



Rev. B1


The float material of construction shall be compatible with the process. The float shall be suitable for the maximum operating pressure of the vessel. 4.6.2 Glass Gauges

Reflex

Reflex gauges shall have a minimum pressure/temperature rating of 69 barg (1000 psig) at 260 deg C. Tempered borosilicate, Pyrex glass, or equal glass shall be used in applications at or below 260 Deg C. 4.6.3 Transparent Type Glass Gauges Transparent armored gauges shall have a minimum pressure/temperature rating of 40 barg (580 psig) at 260 Deg C. Gauges shall have plastic frost shields for applications in which the process liquid has a temperature below 0 Deg C. If illuminators are provided, they shall be suitable for the electrical area classification. Tempered borosilicate, Pyrex glass, or equal glass shall be used in applications at or below 260 deg C. Tubular glass gauges shall not be used unless Company approved and shall never be used in process applications. 4.6.4. Cocks and Ball Checks

Gauge

Gauge cocks and ball checks shall be purchased as assemblies as part of the level gauge. Gauge cocks with ball checks shall not be used in vacuum applications. 5.0

TEMPERATURE INSTRUMENTS 5.1

General

All temperature measurement elements shall be inserted in thermowells except for certain applications such as air temperature measurement for HVAC devices or skin type devices on heaters. Thermocouples, RTD's and Dial thermometers shall be spring loaded into the thermowell to minimize the transfer lag.



Rev. B1


All temperature sensors shall be supplied as complete assemblies, including the measuring elements and terminal heads. The element heads shall be of corrosion resistant metallic weatherproof type certified for use in hazardous area and terminal blocks shall be heat resistant. 5.2 Thermowells Thermowells (TWs) connection type (welded, screwed, or flanged) shall match the applicable Piping Specification. TW material shall be 316 SS unless the process requires other material of construction. All temperature sensors shall be installed in TWs, except for Skin temperature sensors. Consideration shall be given to fluid velocity impact on TWs. Calculations shall be performed using ASME PTC 19.3. TWs shall be constructed from 316 SS bar stock unless otherwise approved by Company. Standard TW bore sizes for temperature elements shall be 0.26 inch and 0.385 inch. Standard TWs shall be of tapered design. 5.3 Thermocouples Thermocouples (TCs) shall be fabricated with 18 gauge wire minimum, in hard packed magnesium oxide insulation with 1/4-inch OD 316 SS sheath, potted extension wire exit from sheath, and grounded hot junction. Inconel sheath and high temperature insulation is required for applications above 600o F. TCs shall comply with ISA MC96.1 and ASTM E230 for TC types B, E, J, K, R, S, and T. Type J shall be used only with Company’s approval. Type J TCs contain iron wire which is subject to corrosion in many locations. The sheathed TC hot junction shall be grounded (except for differential, averaging, or other applications requiring ungrounded).Grounded junction TCs will not give accurate measurements when connected together to measure differential or average temperature. Ungrounded TCs must be used in these applications. Individual TCs connected to measuring instruments are preferred.



Rev. B1


The TC metal sheath shall be connected to the ground connection terminal strip in the TC head via the extension wire shield in the sealed transition piece. Crimped connections are not acceptable. TC heads shall have the following characteristics: Cast aluminum or Company approved alternative. Compression type terminal block with brass terminals and an extra terminal for attaching the extension wire shield connection (Duplex TCs require six terminals.). Two internally threaded conduit connections. 5.4 Resistance Temperature Detectors Resistance Temperature Detectors (RTDs) shall use a 100 ohm, 3-wire, platinum element (resistance measured at 0° C) wound on a ceramic or glass core, hermetically sealed and manufactured in accordance with IEC 60751, Class B. 4wire, Class A shall be used for custody transfer. RTDs shall comply with the IEC 60751 (equivalent to DIN 43760) temperature coefficient of 0.00385 Ohms per Ohm per degree Celsius. RTDs shall be enclosed in a 1/4-inch OD 316 SS protection sheath, with an epoxy sealed transition piece and copper lead wire to a weatherproof head. RTDs shall be fabricated with 18 gauge wire minimum, in hard packed magnesium oxide insulation. Inconel sheath and high temperature insulation is required for applications above 316 deg C (600 deg F). RTDs shall use insulated nickel or nickel alloy wire from the platinum element to the epoxy sealed transition piece where the copper wires shall be attached by welding or soldering. Crimped connections are not acceptable. Wire insulation shall be color coded per ISA. RTD heads shall have the following characteristics: • aluminum or Company approved alternative

Cast

• Compressi on type terminal block with brass terminals with an extra screw provided for attaching the extension wire shield (Duplex RTDs require 6 or 8 terminals.) • internally threaded conduit connections

Two



Rev. B1


5.5 Temperature Transmitters Temperature transmitters shall be of the Smart type being either HART or Foundation Fieldbus depending upon the application. Purchaser will specify the type. The instrument manufacturer shall be the same as selected for the facility control system. Exceptions must be approved by the Company. Temperature transmitters shall use an input from a TC or RTD sensor. RTD is preferred method. Electronic temperature transmitters shall have the following characteristics: • Accuracy, including the combined effects of linearity, hysteresis and repeatability, equal to or better than +/-0.25% of the calibrated span • TC/RTD input type, etc. shall be configurable.

Span,

Transmitters having a TC input shall also provide: • t isolation

Input/outpu

• junction compensation

Cold

• Automatic TC burnout detection with selectable upscale or downscale failure mode. Transmitter burnout shall be configured. • temperature linearization capability for output signal

Built-in

Transmitters having RTD input shall also provide: • Input/outpu t isolation • A dedicated screw connection for use in grounding the RTD extension wiring shield 5.6 Alone Electronic Indicators

Stand

Stand alone electronic indicators (indicators that receive a temperature element as a direct input) shall have the following characteristics: • either TC or RTD signals

Receive

• readout in degrees Fahrenheit or degrees Celsius

Direct



Rev. B1


• that provides a linearized readout

Circuitry

5.7 Temperature Gauges Process temperature gauges shall be of the bimetallic type. Temperature gauges shall have a minimum accuracy of (+/-) 1.0% of span. Temperature gauges shall be designed to install into a TW with a 0.10 inch clearance between the thermometer stem and the TW inside diameter. The stem length of thermometers shall be selected to bottom out in the TW in which they are to be installed. Bimetallic temperature gauges for process measurement shall have the following characteristics: • multiple helix measuring element contained in a dampening fluid

Single or

• 5-inch diameter dial face with a nonglare white finish and black or contrasting color markings • steel, every angle weatherproof case with bezel ring

Stainless

• OD protection tube

1/4-inch

• head or wrench flats

Hexagonal

• standard length

Industry

5.8 Mechanical Thermal Systems

Filled and

The use of filled thermal systems requires Company’s approval. Company approval is required for the use of any direct actuated (e.g., capillary or bimetal) temperature switch. Use of self-actuated temperature regulators requires Company’s approval. 5.9 Installation Requirements TWs shall be located a minimum of ten (10) diameters downstream of the mixing point for liquids.



Rev. B1


TWs shall be located a minimum of 30 diameters downstream of the mixing point for gases or super heaters. TWs mounted in horizontal vessels shall have at least an 18-inch insertion length; however, insertion length shall not exceed 1/2 the vessel diameter. Special requirements such as agitated vessels may require shorter TW installations. Minimum pipe size for TW installation shall be 4”. If a thermowell is required in a smaller pipe size, the piping must be swaged out to 4” for thermowell installation. 6.0

CONTROL VALVES 6.1

General

Ratio of nominal pipe size to body size shall not be greater than 2:1. Valves 1 inch and larger shall be flanged. Valves with welded end connections shall be approved by the Company. Threaded connections are not allowed in the following services: • , toxic, or lethal services

Flammable

• above 400ºF

Services

• subject to deep thermal cycling

Where

• steam pressure is greater than 50 psig

Where

• safe design is required

Where fire-

Control valve body size shall not exceed the line size. Body sizes 1-1/4, 2-1/2, 3-1/2, 5, or higher odd numbers shall not be used without Company approval. If valve calculations indicate a requirement for such sizes, reduced trim may be used in standard size valve bodies. Face-to-face dimensions of valve body shall conform to ISA standards and with the following: Table 2 - Valve Body Face-to-Face Dimensions Body Style

ISA Standard

Globe-style with integral flanges

ISA75.03 or ANSI/ISA75.16 depending on ANSI class rating

Globe-style with separable flanges

ISA75.08.07



Rev. B1

INSTRUMENT REQUIREMENTS FOR PACKAGED EQUIPMENT Page 27 of 49 Flangeless

ISA75.04

Butt-weld-end globe

ISA75.08.04 or ANSI/ISA 75.15 depending on ANSI class rating

Globe-style angle flanges

ISA75.22

The application of valves shall be per Table 3: Table 3 - Acceptable Applications for Valve Body Types Process Characteristic

Valve ANSI Flange Rating (Note 2)

Body Type (Note 1) Globe (Straight)

Globe (Angle)

Wafer Eccentric Disc

Rotary EDisc/ Segmental Ball

Ball and Plug

= 150

M

---

M,O

M,S,O

S,O

= 300

M

---

M,O

M,S,O

S,O

= 600

M

---

---

M,S,O

---

> 900

M

---

---

---

---

= 150

M

M

---

---

---

= 300

M

M

---

---

---

= 600

M

M

---

---

---

> 900

M

M

---

---

---

= 150

---

M

---

M,S (Note 6)

S,O (Note 7)

= 300

---

M

---

M,S (Note 6)

S,O (Note 7)

= 600

---

M

---

M,S (Note 6)

---

> 900

---

M

---

---

---

= 150

M

---

---

M,S,O

M,S,O (Note 8)

= 300

M

---

---

M,S,O

M,S,O (Note 8)

= 600

M

---

---

M,S,O

---

> 900

M

---

---

---

---

= 150

---

---

---

M,S,O

M,S,O

= 300

---

---

---

M,S,O

M,S,O

= 600

---

---

---

M,S,O

---

> 900

---

---

---

---

---

A. Process Gas or Liquid 1. Clean service (liquid – no cavitation or flashing) (Note 4)

B. Process Liquid 1. Clean service (cavitation or flashing condition) 2. Suspended solids (erosive) (Note 3)

3. Corrosive

4. Viscous or nonerosive slurry

Notes: 1

"M" indicates valves that are acceptable for modulating service; "S" indicates valves that are acceptable for shutdown service; "O" indicates valves that are acceptable for on/off service.

2

The ANSI flange rating relates to the pipe flanges for flangeless valves.



Rev. B1


3

Valve selection for nonerosive suspended solids service is the same as that for process gas or liquid (A1).

4

Utility (steam, air, water) valve selection is the same as that for process gas or liquid (A1 and B1).

5

Control valves used in streams that have a combination of the above process characteristics or process characteristics not listed shall be selected according to project requirements.

6

Valve must be installed in accordance with the manufacturer's recommendation.

7

Full port valves only.

8

Plug valves are acceptable in corrosive service. Ball valves are not typically available in corrosion resistant materials.

Flanged connections shall be per the relevant piping class. Flanges with tack welds or flanges with fillet or partial penetration welding are not acceptable. Flangeless valves shall have centering means (e.g., lugs, holes, or equivalent) to ensure proper alignment of valve and gasket. Valve body gasket surface areas shall be the same as that of the mating flanges. Flangeless and wafer-style valves shall not be used in toxic and/or highly corrosive services. Flangeless valves that exceed a body width of 5-1/2 inches shall be subject to Company approval. Lugged body flanges shall be through-bolted. Threaded lugged flanges require Company approval. Welding procedures, performance of welders and welding operators shall meet the requirements of ASME B31.3. Unless otherwise specified leakage class shall be ANSI Class IV as a minimum. Only valves in critical applications that require minimum leakage shall have ANSI Class VI seat leakage rating. Valves with this seat leakage rating shall be submitted to the Company for approval before they are incorporated into the design. Flow direction, where applicable, shall be permanently marked on the valve body. Mechanically linked valves shall not be used for split process flows in lieu of threeway valves without Company approval. The bonnet shall have a bolted design. Extended or finned bonnet shall be used for cryogenic service temperatures. Bonnet bolts shall not be used to attach actuators or mounting brackets. Bonnet gasket shall be compatible with the process, the maximum temperature, and maximum pressure. The gasket material shall be in compliance with the piping specification.



Rev. B1


Gaskets containing asbestos are unacceptable. If the valve is required to be fire safe, the following materials are considered fire safe: •

Metal gaskets

•

Flexible graphite gaskets

Packing material shall be compatible with piping specification. Packing shall not require lubrication. The cooling realized from the use of an extended bonnet shall not be taken into account when selecting the packing. Packing material containing asbestos is unacceptable. For applications in temperatures above 320 Deg C, an extended bonnet shall be used to protect the positioner and actuator from heat. Packing shall conform to manufacturer’s sizing and selection criteria for temperature/pressure curves. The packing material shall be in compliance with the piping specification. For fire-safe applications, graphite-based packing shall be used. Bellows seals shall require Company approval. Packing design shall be approved by the Company before implementation. Control valves shall be designed, selected, and installed to permit easy access of monitoring packing areas prone to fugitive emissions without removing equipment or devices. Manufacturer-recommended bonnet bolts shall be used unless Company specifies differently. Valve bonnets shall be bolted type with a retained-type gasket. The following valve components shall be 304 or 316 SS minimum: • studs and nut (e.g., packing bolts)

Gland

• flange and follower

Packing

Packing glands and followers shall be bolted for valves larger than 1 inch. Carbon steel screwed packing followers shall not be acceptable.



Rev. B1


6.2

Materials

Material, end connections, pressure rating, gaskets, and packing of valve body shall, as a minimum, conform to the applicable piping specification. The Purchaser’s materials engineer shall approve any deviation from the piping specification. Special alloy bodies that differ from the piping specification may be required in conditions such as high temperature, severe erosion, corrosion, or critical applications such as oxygen. Valves shall not be cast iron. Carbon steel shall be the minimally acceptable material for control valve bodies. Control valves in flashing water service require hardened body material or lining such as 5 Cr-1/2 Mo. Plated bolting material shall not be used for pressure-containing parts. 6.3 Valves

Globe

Single-seated globe valves are required unless otherwise approved by the Company. Globe valves shall be used for high-pressure-drop applications, low-flow applications, clean liquid and gas service applications (corrosive and noncorrosive), and clean liquid service, particularly where cavitation, flashing, or noise are design considerations. Globe valves with split bodies shall not be used unless approved by the Company. To reduce the exit velocity of the valve and to dissipate energy, control valve bodies in the following applications shall be no smaller than one size less than line size. The trim size must be specified in severe service applications: • the valve body liquid flow velocity below a maximum of 33 ft/sec

to reduce

• to reduce the valve body gas/vapor outlet velocity below a maximum of 0.3 Mach • when the calculated noise not including special noise trim or other noise reduction methods exceeds the maximum continuous operating noise level 6.4 Valves

Rotary

Rotary valves include all types of ball or plug valves (e.g., ball, segmented ball) and butterfly valves (e.g., eccentric disk).



Rev. B1


The use of rotary valves in applications where cavitation or high-noise conditions are present requires Company approval. Unless otherwise specified, the valve shaft shall be oriented in the horizontal plane. Rotary valves shall be designed such that a mechanical failure will not expel the shaft of the stem from the valve body. The actuator end of the valve stem shall be the spline or keyed design. Shear pins are not acceptable. Shafts shall be made of one piece. The shear safety factor shall be a minimum of 150% at the specified shutoff-pressure-drop condition. The valve stem bearing shall be designed to prevent the stem guide bushing from rotating in the valve body. Bearing material shall be selected to prevent galling of the bearing or valve stem. The valve shaft bearing shall be designed to prevent the shaft guide bushing from rotating in the valve body. Bearing material shall be selected to prevent galling of the bearing or valve shaft and to operate at the maximum and minimum process temperatures. The valve disk and shaft for lined, carbon steel, and stainless steel valves shall be made of stainless steel. Other trim parts shall also be made of stainless steel, as a minimum, or of material that meets the process requirements. Because the disk in wafer-style valves may project beyond the valve body during part of the disk rotation, clearance shall be maintained between the disk and the pipe wall, particularly if the pipe is of heavy wall construction. 6.5 Trim

Valve

On individual valves, the maximum allowable seat leakage ANSI/FCI 70-2 Class shall be stated on the individual control valve data sheet. Control valves that must provide a tight shutoff (TSO) shall be an ANSI/FCI 70-2 Class V or better. The actual leakage rate shall be communicated to the process engineer for approval. Because of close tolerances between the cage and plug, cage trim valves shall be used only in clean liquid, vapor, or gas service. Cage-guided trim in dirty services shall be subject to Company approval. Trim shall be 13 Cr (400 series SS) as a minimum for control valves with cage guided design. Trim for valves in services that contain erosive or solids-bearing fluids shall be hardened with a minimum hardness of 38 Rockwell C. Trim material shall meet the requirements of Table 4 as a minimum.



Rev. B1


Table 4 Hardened Trim Applications Flowing dP psid

Gases

Steam

Water

HC Liquids

0-100

1

2

1

1

100-200

1

2

4

2

200-400

1

2

4

4

500-600

1

3

4

4

600-800

1

3

4

4

800-up

1

3

4

4

Notes: • 1= Manufacture’s standard valve trim (316 or 400 series stainless minimum) • series stainless minimum

2 = 400

• trim (alloy 6 or 316/alloy 6 overlay for the seat ring and plug)

3 = Stellite

• 4= Standard trim 400 series stainless or hard-faced satellite unless valve is cavitating or flashing. • cavitating, use anti-cavitating trim or harden trim according to the manufacturer’s recommendation.

If

• use harden trim (stellite, 440C, or Colmonoy® 6)

If flashing,

Valve stem and plug shall be pinned and welded or be of a one-piece design. Threaded trim parts, except seat rings, shall be pinned or spot-welded to supplement the threaded attachment. In erosive or corrosive services, self-flushing valves shall be preferred instead of permanent flushing connections built into the control valve. Permanent flushing connections shall be subject to Company approval. Valves that require cavitation or noise trim shall be submitted to the Company for approval. Do not use small passage cavitation/noise trim on processes that contain particulates, solids, or plugging material. See section on severe service. If operating temperature exceeds 300 Deg C, guide post areas and rings shall be hardfaced stellite or equivalent. 6.6 Considerations

Sizing



Rev. B1


Valve-sizing procedure shall address the full range of expected flow conditions. Appropriate differential pressure shall be applied as load changes. When sizing a valve, only the characteristics of the plug shall be considered for an accurate understanding of the plug stroke at the various conditions. A positioner with characterization such as equal percentage may be used on trim with an inherent linear characterization to enhance control. Linear trim design shall be used if pressure drop across valve does not vary more than 20% between maximum flow and minimum flow; i.e., dP (max flow) – dP (min flow)/dP (min flow) <20%. If the linear valve does not have sufficient rangeablilty to meet the minimum and maximum conditions, an equal percentage valve is preferred. The manufacturer shall be consulted in sizing of a two-phase, liquid-vapor mixture. Body outlet velocity, defined as the fluid velocity at the discharge flange of a control valve, shall not exceed the following: • for gas, vapor, and steam services except in vacuum services

0.3 Mach

• 0.4 Mach for infrequent services (i.e., services for which the control valve is closed for more than 4 hours during an 8-hour period, including emergency vent and emergency depressurizing services) • for liquid services other than water

33 ft/sec

• for water service

18 ft/sec

• for erosive fluid (e.g., those that contain erosive particles)

20 ft/sec

If manufacturer’s plug guiding or construction governs maximum allowable velocities, manufacturer’s recommended lower velocities shall be used. Final valve sizing will be reviewed and approved by Purchaser. Operating ranges for linear motion and rotary valve types shall comply with the following: • The Cv of control valve through all conditions shall be sized to operate within 15% through 80% of maximum rated Cv of the control valve. • Stem travel/rotation at normal design flow conditions shall be within 40% through 65%.



Rev. B1


6.7 Service

Severe

Severe service valves (e.g., globe or angle with hardened trim, specially designed multi-hole/path cavitation trim, or noise abatement trim) shall be used for applications where conventional valves (globe, ball, butterfly, etc.) are not appropriate because of loss of control characteristics over time. Examples of conditions where severe service valves shall be considered are as follows: Liquid valves • potential exists: (P1-P2)/(P1-Pv) > 0.6

Cavitation

• is a flashing service: (P2 < Pv)

Application

Gas valves • > 0.5 Where

(P1-P2)/P1

• upstream pressure;

P1 is the

• downstream pressure;

P2 is the

• vapor pressure of the process fluid at flowing temperature.

Pv is the

Severe service valves shall be used in the following service applications: • letdown (e.g., high-noise, erosive service) in daily service

Intermittent

• on in daily service where cavitation is predicted

Recirculati

• high vibration and/or high noise is expected from the application

Where

• history of valve failures or need for severe service trim exists

Where

Noise level produced by control valves shall conform to the limits identified on the control valve specification sheet. The noise level is based on 1 meter downstream and 1 meter from the surface of the attached piping. These calculations shall include all process conditions as stated on the data sheet for maximum, normal, and minimum flow. Control valve noise calculations shall be performed for all control valves. For aerodynamic noise of gases, steam, or vapor, ISA 75.17 or IEC 60534-8-3 calculations shall be used. For hydrodynamic noise, the manufacturer method or IEC 60534-8-4 shall be used.



Rev. B1


For the noise calculations to be valid, the maximum valve body exit velocity must be below 0.3 Mach. The Vendor shall advise the Company if the calculated noise level exceeds the 85 dB (A) value as stated on the control valve specification sheet. Hardened materials in trim design shall be used to assist in prolonging the life of the control valve.

6.8

Actuators

Unless otherwise specified, valve actuator shall be pneumatic diaphragm type or piston-type. Vane and other type actuators may be appropriate for rotary-type valves. Use of electric motor or electro-hydraulic actuator may be considered for special applications, particularly if pneumatic power is not available or if very high thrust forces are required. The use of electric motor or electro-hydraulic actuators must be approved by the Company. The actuator shall drive the valve to a safe position on loss of signal or motive power. The actuator shall have an enclosed spring to achieve “fail to safe” action. Valve failure position shall comply with Company-approved P&ID's and the control valve data sheet. When sizing the spring, the process pressure need not be considered if this pressure assists in achieving the “fail to safe” position. If “fail to safe” position cannot be ensured by an enclosed spring, volume tanks may be used with prior Company approval to provide the necessary motive power. The actuator shall be sized to meet control, shutoff, and leakage class at the minimum instrument air pressure identified on the control valve specification sheet. Air exhaust connections shall be oriented and/or equipped to exclude or minimize the entry of water, dirt, and insects. Control valve specification sheet identifies the shutoff criteria for valves on the loss of motive force (e.g., air supply) as follows: • The shutoff classification must be met with spring force only. The spring must be sufficient to maintain shutoff classification at maximum differential pressure on loss of motive force. • On loss of motive force, the valve shall return to required end position using spring force only. Air assistance may be used in conjunction with spring force to maintain shutoff classification at maximum differential pressure. • On loss of motive force the valve shall return to required end position using spring force only. Process pressure assistance may be considered in conjunction with spring force to maintain shutoff classification at maximum differential pressure.



Rev. B1


Sufficient actuator thrusts, tubing diameter, and accessories sizes shall be provided to minimize the dead band, hysteresis, frequency response, and speed of response at all process conditions. Actuators shall be sized to provide the more than the force required to cycle the valve against the worst case process conditions. Maximum differential pressure shall be considered the maximum upstream pressure with the control valve fully closed and downstream pressure at atmospheric pressure. If there is a vacuum on the control valve outlet, then the maximum vacuum pressure on the valve outlet shall be used to determine the maximum differential pressure. Valves in services that cause the control valve stem to stick shall have the actuator sized with a 1.25 design factor. For rotary valve actuators, the manufacturer shall confirm the breakout torque requirements and the maximum percentage opening limit for stable operation. The actuator case shall be rated for the maximum available pneumatic supply pressure. The actuator material of construction shall be the manufacturer’s standard material. Valve yokes shall be ductile iron, high-tensile-strength cast iron, or steel unless specified otherwise in the individual control valve data sheet. Springs, internal parts, fasteners, and hardware shall be resistant to the corrosive effects of the environment. The actuator exterior shall be painted with the manufacturer’s standard paint and color, unless specified otherwise. The sliding stem actuator shall have a valve position indicator that shows position of valve stem against a full travel linear scale. A travel indicator, graduated in opening percentages, shall be attached to the rotary valve actuator end of the shaft. The actuator and associated accessories shall be assembled, piped, and mounted on the control valve and aligned, tested, and shipped as a complete unit. The Vendor shall coordinate the installation and orientation of valve accessories with the valve supplier before final assembly and shipment. Tubing shall be sized to meet the required valve stroke response time. The actuator shall have a permanently attached stainless steel tag. The tag shall be stamped with the manufacturer’s standard data and the Company’s item number. The Vendor shall supply a filter/regulator if required for proper actuator operation. Nominal diaphragm spring ranges shall be 3 to 15 psig or 6 to 30 psig.



Rev. B1


Although some applications will allow the use of actuators that stroke over the input range of from 3 to 15 psig, higher diaphragm pressures often will be required. Generally, the valve should be specified to control and provide the necessary shutoff force with a 6 to 30 psig diaphragm pressure range. If the control valve is provided with a positioner, the instrument air supply shall be regulated at a minimum of 5 psig above the actuator-required pressure to achieve fully open or closed positions (e.g., if actuator requires 6-30 psig, then the supply pressure will be set at a minimum of 35 psig). All devices in the instrument air loop, including air supply filter, air supply regulator, I/P, positioner, diaphragm, actuator housing, and solenoid valves for control valve assembly, shall be rated for the supply pressure or the regulated supply pressure as a minimum. Piston and vane actuators shall be used in the following situations: • valve stem or shaft loading is high

When

• valve action response is require

Where fast

• compact physical installation is required

Where a

If the instrument air header pressure exceeds the rated/designed pressure of any component (e.g., solenoid valve), the instrument air pressure shall be regulated at the design pressure of the component that has the lowest design pressure. 6.9 Positioners and Current-to-Pneumatic Transducers (I/P) A positioner shall be used on all valves unless its use would be detrimental to good process control. The positioner shall be mounted on a plate or boss on the valve dedicated for the purpose. The positioner shall be mounted, piped, and aligned by the valve supplier to provide a complete control valve assembly. The positioner shall be equipped with the manufacturer’s standard supply, input, and output gauges unless otherwise specified. A positioner bypass shall be provided only if specified by the Company. The I/P requires a separate filter/pressure regulator set at a pressure compatible to the device.



Rev. B1


Pressure gages supplied with positioners that are not enclosed in positioner housing shall have stainless steel cases. Pneumatic boosters may be used in conjunction with positioners in applications such as pressure control to achieve the required response time. Digital positioners shall be HART or Foundation Fieldbus as specified on data sheets. Electropneumatic transducers (I/P) shall normally provide a 3 to 15 psig output signal and shall be configured to be direct acting rather than reverse acting. They may be integrally mounted on control valve, with Company approval, if transducers are rated for operating conditions, such as maximum temperature and vibration. 6.10 Handwheels Control valves may have a handwheel operator only if specified by the Company. When used, the handwheel operator shall be continuously connected and shall operable through an integral declutching mechanism. The operator may be side mounted, lockable, or screw or gear driven if accessibility is not a consideration. The handwheel operator on a rotary valve shall be mounted directly on the shaft, and the clutch shall be installed so that it can be declutchable. Top-mounted jacks or handwheels shall not be used unless approved by Company. A valve-to-open direction arrow shall be permanently marked on the handwheel. Hand wheels shall not be used to eliminate block and bypass valves and they shall not be used as limit stops. 6.11 Volume Tanks, and Quick Exhaust

Boosters,

Boosters shall be provided when necessary to achieve the required stroke time. A volume booster shall be used only if approved by Company. Instrument air supply piping to boosters must be of adequate size not to limit the supply to the boosters. The piping size selection must also include drops across filters and regulators. Normally, pipe is used for supplies. Larger pipe may be required for extensive pipe runs. The flow through the boosters must not be restricted. In some cases, connections in the actuators must be enlarged. Conditions may exist making it desirable for the valve to move rapidly in one direction but slower in the other. This can be accomplished by selectively restricting one side of the booster or boosters. The use of a volume tank must be approved by Company. Volume tank shall be sized to fully stroke the valve through two travel cycles. If the volume tank, by virtue of size, pressure rating, or local regulation must conform to Part U-1 of Section VIII, Division 1, of the ASME Boiler and Pressure



Rev. B1


Vessel Code, capacity tank shall be ASME Code stamped and be equipped with a pressure relief device. Volume tank shall be equipped with the proper accessories (tubing, fittings, pressure transmitters, solenoid valves, etc.) to ensure that the valve fails in the safe position. 6.12 valves & blowdown valves

Shutdown

These valves shall normally be line size ball valves in accordance with the project specification “Piping and Valves Material Specification”. Reduced bore valves shall be considered unless advised otherwise in data sheets. Valve design shall be shall be as per API 6D and shall be fire tested in accordance with BS 6755 Part 2 or API 6FA or API 607. Unless otherwise specified Pneumatic, actuators shall be used. Actuators shall be sized as per API 6D under the most adverse process conditions for both seating and unseating operations against the maximum differential pressure utilizing minimum pneumatic supply pressure. De-energizing the actuator solenoid valves shall cause the valve to fail to its safe position. The valve shall not return to its normal position until the solenoid valves are electrically reset. The selected elastomer material for valve seals shall be capable of withstanding compression and decompression effects arising out of closing and opening of the valve. Valve shall be equipped with adjustable controls to regulate their stroking speed. For PSD, ESD valves the maximum allowable closure time from initiation of signal shall be 3 seconds plus 1 second for every 1” of valve body size. Whereas for BDV's the maximum valve opening time shall be 10 seconds upon receiving the command. Vendor shall clearly specify the opening and closing times. All valves shall have an integral position indicator. Accessories such as air filter regulator, solenoid valve etc. shall be assembled on a panel and mounted on the actuator. Solenoid valves shall be “fail to safe”. Loss of power or pneumatic supply shall cause the shutdown/blow down valve to its “fail to safe” position as specified in the valve data sheet. Solenoid valves shall be suitable for Zone 1, GR IIB, and T3 and certified by BASEEFA or equal. Valve torque tables shall be provided and valve torque shall be 1.25 times the actuator shear torque. The design and selection of actuators for the application is Vendor responsibility. All Valves shall be tested at maximum DP to prove actuator integrity.



Rev. B1


6.13 Appurtenances

Valve

6.13.1 Regulators and Auxiliary Equipment

Air

Set

Air sets that are required at valves shall be rigidly mounted to valve yoke if mounting pads are provided. Air sets shall not be supported by pipe nipples from positioners. Air sets for positioners bolted to control valve yoke shall be permitted. 6.13.2 Valves

Solenoid

Solenoid valves shall be mounted and tubed by the valve vendor unless directed differently by the Purchaser. For instruments without terminal strips, the valve Vendor shall provide a terminal strip and housing. Solenoid valves and coils shall be rated for continuous duty and shall have a minimum of Class F high-temperature encapsulated coils; Class H coils are preferred. A solenoid valve used for tripping a control valve shall be between the positioner and actuator or in the tubing that provides the motive power to the actuator. Tripping the solenoid valve shall provide sufficient capacity to exhaust the actuator chamber air volume within the time required to allow the valve to fail in a safe position. If solenoid valve Cv is not sufficient, a “quick exhaust” valve shall be provided that works in conjunction with the tripping solenoid valve if needed. If the solenoid valve vent port is open to the atmosphere, it shall have an insect screen. The solenoid valve shall be capable of switching under conditions of maximum and minimum operating differential pressure. Instrument air supply piping must be of adequate size to stroke the valve in the time specified. 6.13.3 Position Transmitters and Switches Position transmitters and switches shall be mounted and calibrated by the valve vendor. Position transmitters will generally be used in lieu of position switches. Position transmitters shall normally be Smart using either HART or Foundation Fieldbus whichever. Purchaser will specify type. When used, position switches shall be hermetically sealed. 7.0

CONTROL PANELS



Rev. B1


7.1

General

Control panels intended for installation indoors or outdoors shall comply with the relevant Area classification. Where a Vendor’s standard control panel is supplied, the Vendor shall provide details, including heat dissipation and panel cooling method, at the time of tendering for approval by the Company/Purchaser. No process fluids or process gases shall be permitted inside any local panel. Prior to fabrication, Company/Purchaser’s acceptance shall be required for layout of panel face-mounted and internal components, design of system cabinets, detail drawings, materials of construction, and nameplate wording. Plastic engraved nameplates shall be mounted to the panel with stainless steel screws. 7.2 Construction

Design &

Free standing panels shall be designed as cabinets with base frame work and plinth or with legs. Free standing cabinets shall have a minimum of four hold-down bolt locations. Lifting eyes are required on top, each one capable of supporting the fully equipped panel during shipping or placing operations. Panels for outdoor use shall have a minimum 3mm thick steel plate vertical face. All panels shall be totally enclosed with access door or doors that provide sufficient clearance for full internal access, and have all stainless steel hardware. Panels shall have a self-supporting box type main framework made of steel standard structural shapes coated for the environment, and have lifting provision integral to panel box frame. Rear access doors shall be flush fitting, gasketed, secured with three-point latches. Panel doors shall be fitted with formed neoprene rubber seals to prevent entrance of dust or moisture and to maintain the specified degree of protection. Foam rubber or felt seals will not be accepted. If pneumatic instruments are required in the control panel, air supply design shall include dual air filters and regulators, and the capability of each regulator and filter to pass the required air supply volume and pressure. Full block and bleed valves shall be provided for separate maintenance of each set of filters and regulators. Pneumatic signal tubing shall enter local control panel through the sides via bulkhead union fittings. Panels intended for installation outdoors shall be fabricated from 316 SS. Panels intended for installation indoors shall be protected against corrosion in accordance with the requirements of Specification AGS-18, Protective Coating.



Rev. B1


Any panel, which requires ventilation, shall be installed indoors. Ventilation arrangements shall not diminish the degree of ingress protection below IP42. Components within ventilated panels shall be treated to prevent the harmful effects of moisture drawn through the panel. Panels, which require forced ventilation, shall be provided with two or more fans. The design flow of ventilation air shall be achieved even if one fan fails. 7.3

Access

The panel shall be located such that the doors or covers can be opened fully for maintenance access. Panel face instruments shall be suitable for the specified environmental conditions, flush mounted, provided with manufacturer’s standard finish, and identified by means of instrument manufacturer’s standard nameplate or by plastic engraved nameplates. Control panels shall be located to allow operation of the mechanical equipment and panel instruments without exposure of personnel to potentially unsafe conditions. The location of panels shall allow for performance of normal maintenance of all portions of the packaged equipment. Consideration shall also be given such that location will not be liable to impact damage. The chosen location shall provide adequate space for cable bends. 7.4 Electrical

Panel

-

Pilot lights, pushbuttons, and switches shall be oil-tight, heavy duty, and have open screw type terminals. The pushbuttons shall be supplied with protective guards or they shall be recessed mounted. A minimum of 20% extra space for wireways and cable trunks shall be provided for future requirements. Cable entry location for outdoor panels shall normally be bottom entry. Changes to this requirement must be coordinated with the Company’s Performing Agent. Where enclosures are designed with gland plate entries for cables, the Vendor shall design and execute a drilling pattern for each gland plate, to accommodate the designated number and size of cable glands. Holes shall be provided for any cables to be installed by the Vendor and for any cables to be installed by the Company/Purchaser. All unused gland holes shall be plugged with Ex certified and rated plugs in nickel-plated brass or stainless steel. The drilling pattern shall provide adequate space to install and tighten each gland whilst minimizing the total space consumed. Unused space shall be concentrated on one side of the gland plate. If the gland plate has unused holes, these shall be filled with temporary plugs. The temporary plugs shall not impair the ingress protection or the hazardous area protection of the enclosure. On stainless steel panels, gland plates shall be in 3mm stainless steel. On painted panels, gland



Rev. B1


plates shall be 3mm stainless steel or 4mm brass. No aluminum gland plates shall be used. All metal parts (except parts of circuits intended to conduct electricity), on or within the control panel, shall be bonded together and connected to an earth terminal on the outside of the panel. The earth stud shall be fixed to a gland plate, provided this does not infringe upon the requirements for ingress protection or hazardous area protection. This requirement applies equally to panels with metallic or non-metallic enclosures. On panels containing power circuits, the earth terminal shall be equal in size to the largest of the power terminals. On panels containing only control or communications or instrument circuits, this earth terminal shall be a stud, with a thread size of not less than M10. Doors, removable panels and gland plates shall all be bonded to the terminal box earth with flexible, insulated conductors. The terminal blocks shall be readily accessible, screw-type, 600V terminal blocks and shall be provided for all external wiring connections for controls, relays, meters, interlocks and alarms. Terminals shall be protected to a degree not less than IP20 to prevent accidental contact during inspection or maintenance. Terminal blocks shall have separate terminals for incoming and outgoing wires. No more than two wires may be connected to any terminal. Individual terminals shall be provided for each outgoing conductor. Interconnection of terminals on the same terminal block shall be done by the use of purpose-made jumper bars or links. The terminal blocks shall be arranged vertically, the minimum distance between the terminal block and trunking shall be at least 100 mm, but always consistent with cable and wire arrangement and identification. Terminals shall be removable series and fitted on DIN mounting rail. They shall have 8 mm pitch minimum and sized according to cores/wires cross section. Sufficient terminals shall be provided to terminate all assigned cores and all spare cores in every control or instrument cable. In addition, a number of spare terminals shall be provided. The quantity of spare terminals shall be at least 20% of the quantity of assigned terminals. Sufficient space shall be allowed between gland plate and terminal block to accommodate the bending radius of the conductor. Special care shall be taken to provide sufficient space for the bends of power conductors. Terminal markings for control and instrument cable connections shall be in accordance with the relevant wiring diagrams. Terminal block insulation shall be of a non-rigid, non-hygroscopic, non-tracking, non-flammable material. Terminals in the following services shall be segregated from each other by barrier strips within control panels or switchgear:



Rev. B1


• power related control systems

Power and

• analog signals

Instrument

• digital signals

Instrument

• y shutdown systems

Emergenc

• gas systems

Fire and

• safe circuits

Intrinsically

• Control, Indication and Alarm

Protection,

Control and alarm circuits shall fail to a safe mode. The device de-energized state shall be the safe mode. Loss of control power or an open circuit shall cause a safe mode. A closed contact shall indicate healthy conditions. An open contact shall initiate an alarm or shutdown condition. Controls and indicators shall be mounted on the front of the enclosure or panel. They shall be labeled to indicate their function. Lamps shall be colour coded to indicate various circuit conditions: Red:

Circuit is ON / CLOSED / RUNNING

Green:

Circuit is OFF / OPEN / STOP

Amber:

Circuit is Faulty

All indicating lamps shall be neon or cluster-LED type. Lamp holders shall be positively located in the panel so that they cannot turn or work loose during lamp replacement. Reliance on the tightness of the securing nut shall not be accepted for this purpose. Lamp holders shall incorporate an individual “push to test” function, or the panel shall have a common lamp test push button. Lamp holders shall incorporate a label tag and all lamps shall be labeled to indicate their function. Suitable circuit protection shall be supplied for controls so that any one electrical fault does not affect more than one unit or system. The protection can be accomplished by either circuit breaker or fuse. The protection devices shall isolate all wires. All fuses and routine service adjustments shall be readily accessible without removing the equipment from service. 8.0

GENERAL ELECTRICAL REQUIREMENTS



Rev. B1


8.1 Wiring and Earthing

Cabling,

The Vendor supplying equipment package shall provide, install, connect and test all cabling, wiring and earthing which is wholly within the Package limits. The Company/Purchaser shall be responsible for the supply, installation, and connection and testing of all cabling, wiring and earthing between the battery limits and connection points on the platform. For Instrumentation and control cabling, the battery limits for cabling shall be at the outgoing terminals, in Junction boxes provided by the Package Vendor, on the edge of the skid. Vendor shall carry out all the work that is necessary to complete the cable and earthing installation on the Package skid. The work shall include but is not limited to the following: • Supply and installation of all cable racks, trays, ladders, other supports, separating strips and fixing materials for the cables. • of cables

Installation

• of earthing conductors

Installation

• of any required supports, fixing materials, cable markers, etc

Provision

• all gland plates

Drilling

of

• all cable glands

Supply

of

• and labeling of cables

Glanding

• n and labeling of cable cores

Terminatio

8.2 Boxes and Junction Boxes

Terminal

Instrument terminal and junction boxes shall be supplied and installed in accordance with the requirements of AGS-11, Electrical Work and AGS-12, Electrical Requirements for Mechanical Packaged Equipment 8.3 Trays and Ladders

Cable



Rev. B1


Cable trays and ladders shall be supplied and installed in accordance with the requirements of AGS-11, Electrical Work. The Package shall be equipped with sufficient ladders, trays and supports for cables installed by the Vendor. It shall also be equipped with sufficient ladders, trays and supports for Company/Purchaser-installed cables to the Package. In addition, the system of ladders and trays shall allow for 20% spare capacity. All cable tray/ladder accessories, such as splice plates and divider strips etc. shall be supplied by the cable tray/ladder manufacturer. The use of Vendor fabricated accessories is not permitted. 8.4 Installation

Cable

All cables provided by the Vendor shall comply with Specification AGS-53, Electrical and Instrument Cables. Cables installation and arrangement (layers, spacing, segregation, etc) shall be in accordance with the requirements of AGS-11, Electrical Work. Cable splicing is not allowed. 8.5 and Protection of Cables

Storage

During any period of storage prior to installation, the Vendor shall ensure that each end of each stored cable is sealed with a heat shrink cap. When a cable has been pulled into place and cut to length, the Vendor shall seal each end, with a heat-shrink cap, unless the cable is scheduled for termination in the next seven days. All such cables shall remain sealed until immediately prior to actual terminating. 8.6 Marking

Cable

Cable marking shall be in accordance with referenced Company specifications. Cable numbers shall be related to the Purchaser’s cable schedule. Vendor shall coordinate cable numbering with the Purchaser. 8.7 Cable Transits (MCT)

Multi

Where cable installation is to be performed offshore, the onshore Vendor shall fill the space in the transit with spare solid blocks and apply only finger tight compression to the transit. The offshore installation contractor shall remove the spare solid blocks and install suitably sized insert blocks for the offshore cables.



Rev. B1


All transits shall be installed strictly in accordance with manufacturer’s installation Instructions. It shall be Vendor’s responsibility to select and install the correct size of transit block to suit the appropriate cable diameter. 8.8

Earthing

Earthing within the package shall be the Vendor's responsibility. The structural steel skeleton of the platform shall be the main platform earth and current return path. Any metallic part or structure on the package, except for conductors intended to carry electricity, shall be bonded to this main platform earth. Except as specified here, earthing shall be in accordance with referenced Company specifications. Frames of metallic housings, control cabinets, panels, control stations, et cetera, shall be separately earthed through a proper earth terminal. Conductors shall be fitted with approved insulated crimped pins for connection into clamp type terminals or fitted with ring type crimp lugs for stud terminals, earth bosses or studs. All instrument power cable armour shall be earthed at both ends by means of an earthing tag washer. All instrument signal cables shall be earthed at the control panel end only. Instrument signal cables shall never be earthed at any interim location. Cable armour earthing shall be connected on non-earthed terminals to provide for armour continuity. Fieldbus cable installation, if required, shall comply with the requirements and recommendations of the Fieldbus Foundation. 9.0

ADDITIONAL REQUIREMENTS 9.1 Identification Instruments, equipment, and enclosures shall be identified before shipment by permanently affixing a name tag, or affixing a stainless steel tag with stainless steel fasteners. Plastic nameplates shall be three-layer laminate material with black lettering engraved on a white background. Safety systems shall have white lettering on a red background. 9.2 and Testing

Inspection

A written test procedure for conducting a Factory Acceptance Test (FAT) and Site Acceptance Test (SAT) (if required) of instrumentation, protective logic, safety functions, and control functions shall be submitted by the Packaged System Vendor for approval by Purchaser a minimum of 6 weeks before the scheduled test. FAT and SAT shall be quoted when specified on the data sheets or the VDR. Vendor shall notify Purchaser of the estimated time required to perform the acceptance testing.



Rev. B1


Unless otherwise specified, Purchaser shall require a minimum notice of 1 week in advance of scheduled acceptance test. Material, workmanship and compliance with all specifications, shall be subject to inspection and verification by Company/Purchaser’s representative during and after fabrication. Company/Purchaser's inspection or lack thereof shall not relieve the Vendor from compliance with this Specification. Adequate time, space, facilities, utilities, test equipment, and assistance to allow performance of inspection and testing shall be provided at the Vendor’s facility. Vendor shall provide all necessary test equipment. All instrumentation and control systems shall be carefully inspected, checked out, and tested by Vendor prior to Company/Purchaser’s scheduled acceptance test and checkout. Any items found not in compliance with this Specification during the Vendor test shall be listed for Company/Purchaser review/acceptance along with a statement giving reasons for noncompliance. Vendor’s test report, including a record of any corrections performed, shall be provided to the Company/Purchaser’s representative before Company/Purchaser’s factory acceptance test. 9.3 Preparation for Shipment Instruments that may be susceptible to physical damage shall be disconnected, packaged separately, and securely shipped with the Packaged Equipment. Instruments removed from the equipment before shipment shall be tagged and boxed separately from any mechanical parts or equipment. The container(s) for the removed instruments shall be clearly marked as required by the purchase order. Instrument electrical conduit, fittings, and openings shall be sealed with a threaded, lubricated plug. Pneumatic, vent, and drain connections shall be weather protected using plastic plugs or caps. Instruments shipped separately shall be protected by sealed packaging and shipped with desiccant inside the instrument or sealed package. Instruments shipped installed on the Packaged Equipment shall be weatherproofed for shipment and for outdoor storage at either the Company or the Purchaser’s facility. The equipment shall be free of burrs, sharp edges, etc.



Rev. B1


9.4 Documentation Requirements The Vendor Data Requirements List, (VDR), provides the document type and the required quantities for each document along with the required delivery schedule. Electronic files shall be provided per the VDR.

A-1-GEN-IN-PH-0004

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