2014-4800-1l-0008 rev d piping design basis
DESCRIPTION
for STT projectTRANSCRIPT
COMMENTS RESPONSE SHEET SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
DETAILED ENGINEERING AND PROCUREMENT ENGINEERING SUPPORT SERVICES
Title: PIPING DESIGN BASIS
FOR ST-PIP, ST-LQ, WHP-C Document number: 2014-4800-1L-0008_Rev C
Rev: A
Page 1 of 2
Item Clause/
Section Comments (Reviewer)
Reviewer
Initials Action Undertaken (Originator)
Close
Out(Y/
N)
1 3.1.1
- To add ISO 14962 part 1 to part 3
- What type of epoxy for end caps of tee.
- Replace riser by outlet discharge.
CLJOC
- Incorporated in next Rev
- This project used target tees
with solid end. Epoxy for end
caps of tee is not used.
Y
2 3.1.3
- This document number is Stress Critical line list for
PIP. Should follow the process line list for ST-PIP, ST-
LQ and WHPC. (Typ. comment)
PTSC-MC - Incorporated in next Rev
Y
3 3.1.4
- This document number is Stress Critical line list for
PIP. Should follow the process line list for ST-PIP, ST-
LQ and WHPC. (Typ. comment)
PTSC-MC - Incorporated in next Rev
Y
4 3.2.3 - Need description of sealing method CLJOC - Incorporated in next Rev Y
5 3.5
- Should not indicate the version or just mention "latest
ver.". STTFFD project use version 5.3
- To correct the version for CAESAR-II
CLJOC/
PTSC-MC - Incorporated in next Rev
Y
6 3.7
- The requirement of Temporary support will be
indicated and markup on piping stress iso drawing of
stress analysis report.
PTSC-MC - Incorporated in next Rev
Y
7 3.14 - To add 2500# and below
- To add valve pressure API 10000# CLJOC - Incorporated in next Rev
Y
8 3.16.3 - This is not consistent with isolation philosophy CLJOC - Incorporated in next Rev
Y
9 4.4.1 - Correct description flange for ASME class 150 - 2500 CLJOC - Incorporated in next Rev
Y
COMMENTS RESPONSE SHEET SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
DETAILED ENGINEERING AND PROCUREMENT ENGINEERING SUPPORT SERVICES
Title: PIPING DESIGN BASIS
FOR ST-PIP, ST-LQ, WHP-C Document number: 2014-4800-1L-0008_Rev C
Rev: A
Page 2 of 2
Item Clause/
Section Comments (Reviewer)
Reviewer
Initials Action Undertaken (Originator)
Close
Out(Y/
N)
10 4.4.5
- Stud bolts for API 5000# and 10000# shall have a full
continuous thread with the length of stud bolts shall be
in accordance with API 6A
- To check with material specialist about this. To specify
clearly about PTFE requirement for bolt:
Internal/external of valve; for SS, DSS spec.
- Conflict with piping material class spec, to check and
update.
PTSC-MC - Incorporated in next Rev
Y
11 4.4.11 - Consider require for splash zone only. PTSC-MC - Incorporated in next Rev
Y
12 5.2.2 - Utility Air Stations CLJOC - Incorporated in next Rev
Y
13 Table 3 - To update including Spec. B8 CLJOC - Incorporated in next Rev
Y
SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
DETAILED ENGINEERING AND PROCUREMENT
ENGINEERING SUPPORT SERVICES
PIPING DESIGN BASIS FOR ST-PIP, ST-LQ, WHP-C Doc. No.: 2014-4800-1L-0008
Rev: D
Page No.: 2 of 47
REVISION RECORD SHEET
No. Rev. No. Content of Revision Date of Revision
1 B Approved for Design (FEED) 11-12-14
2 C Issued for Review
Updating and developing from FEED stage 22-05-15
3 D
Issued for Approval
- Revised as Per CLJOC & PTSC-MC‟s comment
marked in vertical line.
29-06-15
SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
DETAILED ENGINEERING AND PROCUREMENT
ENGINEERING SUPPORT SERVICES
PIPING DESIGN BASIS FOR ST-PIP, ST-LQ, WHP-C Doc. No.: 2014-4800-1L-0008
Rev: D
Page No.: 3 of 47
TABLE OF CONTENTS
1.0 INTRODUCTION 5
1.1 DESCRIPTION OF FACILITIES 5
1.2 SCOPE 5
1.3 P & ID 6
1.4 MATERIAL REQUIREMENT 6
1.5 DEFINITION AND ABBREVIATION 6
2.0 REFERENCES 7
2.1 COMPANY SPECIFICATIONS 7
2.2 CODES AND STANDARDS 7
2.3 VIETNAMESE STANDARDS 9
2.4 CONFLICTS 9
3.0 PROCESS PIPING 9
3.1 PIPE DESIGN 9
3.2 LINE SIZING 11
3.3 LAYOUT AND CLEARANCE 13
3.4 CLEARANCE 14
3.5 THERMAL EXPANSION AND SUPPORT 15
3.6 COLD SPRING DESIGN 16
3.7 HANGERS AND SUPPORTS 16
3.8 ADJUSTABLE HANGERS 17
3.9 ANCHORS AND GUIDES 18
3.10 SPRING HANGERS 18
3.11 PROCESS DRAINS AND VENTS 18
3.12 CLOSED DRAIN SYSTEM 19
3.13 STRAINERS 20
3.14 VALVES 21
3.15 PRESSURE SAFETY VALVES (PSV) 24
3.16 PIPING TO PUMPS, VESSEL AND EQUIPMENT 25
4.0 PIPING CONNECTIONS 27
4.1 GENERAL 27
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4.2 BUTT WELD CONNECTIONS 27
4.3 SOCKET WELD CONNECTIONS 28
4.4 FLANGE CONNECTIONS 28
4.5 THREADED CONNECTIONS 32
5.0 UTILITY PIPING 33
5.1 SEAWATER, UTILITY WATER AND POTABLE WATER PIPING 33
5.2 UTILITY AIR AND INSTRUMENT AIR PIPING 34
5.3 HEATING MEDIA PIPING 35
5.4 FIREWATER SYSTEM 35
5.5 DECK DRAIN SYSTEM 36
6.0 PIPING AND INSTRUMENT DIAGRAMS (P&ID’S) 38
6.1 DRAWING LAYOUT 38
6.2 DRAFTING DETAILS 39
7.0 IDENTIFICATION SYSTEMS AND ABBREVIATION 40
7.1 SERVICE DESIGNATIONS 40
7.2 LINE NUMBERING SYSTEM 40
7.3 STANDARD ABBREVIATIONS 41
TABLE 1: SERVICE DESIGNATIONS [PER P&ID LEGEND SHEET] 41
TABLE 2: STANDARD ABBREVIATIONS 42
TABLE 3: PIPING SYSTEM SPECIFICATION 45
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1.0 INTRODUCTION
1.1 DESCRIPTION OF FACILITIES
The Su Tu Trang (White Lion) field is located at the South end of Block 15-1 (approximately
20km‟s South of STV) in approximately 56 meters of water. The Block 15-1 contract area is
located in the Cuu Long Basin offshore southern Vietnam, 180 kilometres southeast of Ho Chi
Minh City.
The development of Su Tu Trang started in September 2012 with the Long term Production
Testing Phase (LTPTP). It consists of a remote, unmanned wellhead platform (WHP-C) that
produces to and is controlled from the Su Tu Vang CPP. The platform has the capability of
handling up to 4 high pressure gas wells. Present production is 6,000 BPD of condensate and 50
MMSCFD of gas and all the STT produced fluids are exported for processing to the Su Tu Vang
CPP via a multiphase 12” pipeline.
Production of the Su Tu Trang Field is now bottlenecked by the CPP process capacities, and
most significantly by the gas export pipeline to shore and the gas sales demand in South
Vietnam.
The purpose of the Phase 1 of Su Tu Trang Full Field Development is to face these restrictions
by allowing the increase of the condensate production while keeping the gas export flow rate
steady. It will also provide more reservoir information to support STT Full Field Development
Phase 2 that will significantly increase gas production/export.
The Project consists of the installation of a reinjection platform (ST-PIP) bridge-linked to the
existing WHP-C, the drilling of two new wells on ST-PIP and the conversion from producers into
injectors of two existing wells on WHP-C. The outcome of the project will be a continuous
production rate of 150 MMSCFD, a reinjection rate of 100 MMSCFD, an export rate of 50
MMSCFD to Bach Ho via CPP (no change), and an incremental condensate production of 13,000
BPD.
ST-PIP will be bridge-linked to a separated living quarters platform designed for 20 pax during
Phase 1, but extendable to 60 pax at a later stage. In addition to accommodation, ST-LQ will be
equipped with most of the utilities for ST-PIP. It is also designed to be bridge-linked to a
separated Central Gas Facility Platform (CGF) in the future (Phase 2).
1.2 SCOPE
This Specification, in conjunction with the other COMPANY Technical Requirements, defines
the requirements for the design, layout, support and flexibility of piping system used in upstream
oil and gas production facilities and for VENDOR furnished equipment packages. These
requirements include process and mechanical design requirements and valve selection guidelines.
This specification governs piping systems provided in accordance with API Recommended
Practice 14E “Design and Installation of Offshore Production Platform Piping Systems” and
ASME B31.3 “Process Piping”. FEED, contractor should endeavor to cover all basic
requirements. Detail Engineering requirement fabrication mode activities shall be covered at
EPCI stage.
This specification shall also cover all Process and Utility Piping on the STT Complex platform.
SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
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1.3 P & ID
The P&ID's and other COMPANY Specifications indicate the required piping class and valve
types for use in the detail design. VENDOR/CONTRACTOR shall strictly adhere to these
documents.
1.4 MATERIAL REQUIREMENT
Valve Material requirements; pipe schedule, sizing & selection criteria; valve tagging system;
line numbering system; and Material Specification tables are provided in COMPANY
Specification 2014-4800-1L-0006 Valve Specification and Material Specification
1.5 DEFINITION AND ABBREVIATION
1.5.1 Definition
Definitions used in this document are described below:
COMPANY
[CPY]
CUU LONG JOINT OPERATING COMPANY. [CLJOC]
EPCI CONTRACTOR
[CTR]
PTSC MECHANICAL & CONSTRUCTION CO., LTD.
[PTSC M&C]
DETAILED
ENGINEERING
INTEGRATED TEAM
[DE]
TECHNIP VIETNAM CO., LTD. [TPVN]
PTSC MECHANICAL & CONSTRUCTION CO., LTD.
[PTSC M&C]
PETROVIETNAM ENGINEERING COMPANY. [PVE]
VENDOR Party responsible for manufacturing and/or packaging of
equipment.
SUB-VENDOR Other entity employed by VENDOR to perform work and/or
supply equipment.
1.5.2 Abbreviation
Abbreviations used in this document are described below:
ST-PIP Reinjection Platform
ST-LQ Living Quarter Platform
WHP-C Long Term Production Test Program
STT Su Tu Trang
MSL Mean Sea level
DE Detailed Engineering
FEED Front End Engineering Design
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2.0 REFERENCES
2.1 COMPANY SPECIFICATIONS
The specifications listed shall be complied with unless contradicted by the philosophy or by a
code or standard.
The philosophy then the code or standard shall have higher priorities than the specification in that
order.
The following COMPANY specifications supplement this specification:
o 2014-4800-1H-1001 Mechanical Basis of Design
o 2014-4800-1H-1001 Process Design Basis
o 2014-4800-1L-0007 Piping Material Classes Specifications
o 2014-4800-1L-0006 Valve Specification and Material Specification
o 2014-4800-1H-0005 Piping Standard Details
o 2014-4800-1H-0004 Pipe Stress Analysis Philosophy
o 2014-4800-1M-0001 Manual Valve & DBB valve datasheets
o 2014-4800-1L-0004 Painting and Coating Specification
o 2014-4800-1L-0005 Insulation and Personal Protection Specification
o 2014-4806-4L-0001 Instrument Design Specification
o 2014-4806-4L-0002 Instrument Installation Specification
2.2 CODES AND STANDARDS
The codes and standards (Latest editions) are mandatory and shall be complied.
The design of piping systems and the piping material data sheets shall be in accordance with the
latest edition of the codes and standards listed below. A particular code or standard that will
apply during the course of design and fabrication shall be the latest revision published at the time
of issuance of the bid inquiry.
o American Society of Mechanical Engineers (ASME).
B1.20.1 Pipe Threads, General Purpose (Inch)
B16.5 Pipe Flanges and Flanged Fittings, NPS ½" through NPS 24
B16.9 Factory-Made Wrought Steel Butt-Welding Fittings
B16.10 Face-to-Face and End-to-End Dimensions of valves
B16.11 Forged Fittings, Socket-Welding and Threaded
B16.20 Metallic Gaskets for Pipe Flanges - Ring-Joint, Spiral Wound and Jacketed
B16.21 Nonmetallic Flat Gaskets for Pipe Flanges
B16.34 Valves - Flanged, Threaded and Welding End
B16.25 Butt-Welding Ends
B16.47 Large Diameter Steel Flanges NPS 26 through NPS 60
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B16.36 Orifice Flanges
B16.48 Link Blanks
B18.2.1 Square and Hex Bolts and Screws Inch Series
B18.2.2 Square and Hex Nuts (Inch Series)
B31.3 Process Piping
B31.4 Pipeline Transportation Systems for Liquid and Slurries
B31.8 Gas Transmission and Distribution Piping Systems
B36.10 Welded and Seamless Wrought Steel Pipe
B36.19 Stainless Steel Pipe
Section V Non-Destructive Examination
Section IX Qualification Standard for Welding and Brazing Procedures, Welders,
Brazers and Welding and Brazing Operators
o AISC Manual of Steel Construction (pipe supports only)
o ANSI / AWS D1.1 Structural Welding Code - Steel (pipe supports only)
o NACE MR0175 Sulfide Stress Cracking Resistant Metallic Materials for
Oilfield Equipment
o American Petroleum Institute (API)
SPEC 5L Line Pipe
SPEC 6A Valves and Wellhead Equipment
SPEC 6D Pipeline Valves (Steel Gate, Plug, Ball and Check Valves)
RP 550 Manual on Installation of Refinery Instruments and Control Systems
RP 14C Recommended Practice for Analysis, Design, Installation and Testing of
Basic Surface Safety Systems for Offshore Production Platforms
RP 14E Recommended Practice for Design and Installation of Offshore Production
Platform Piping Systems
RP 520 Sizing, Selection and Installation of Pressure-relieving Devices in
Refineries
RP 521 Guide for Pressure Relieving and Depressuring Systems
STD 598 Valve Inspection and Testing
Technical Report 938-C Use of Duplex Stainless Steels in the Oil Refining Industry
o Code of Federal Regulations (CFR)
Title 29, 1910, OSHA Occupational, Safety & Health Administration
Title 30 Part 250, MMS Minerals Management Service
o American Society for Testing and Materials
A 36 Specification for Structural Steel
A 578/A 578M Straight-Beam Ultrasonic Examination of Plain and Clad Steel Plates for
Special Applications
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D2846 Chlorinated Poly Vinyl Chloride (CPVC) Plastic Hot and Cold Water
Distribution Systems
o Manufacturers Standardization Society of the Valve and Fitting Industry (MSS)
SP-6 Standard Finishes for Contact Faces of Pipe Flanged and Connecting-End
Flanges of Valves and Fittings.
SP-25 Standard Marking System for Valves, Fitting, Flanges and Unions
SP-44 Steel Pipeline Flanges
o National Fire Protection Association (NFPA)
NFPA 13 Installation of Sprinkler Systems
NFPA 15 Water Spray Fixed Systems for Fire Protection
NFPA 24 Private Service Mains and Their Appurtenances
o Engineering Equipment and Materials Users Association (EEMUA)
Publ. 146 90/10 Copper Nickel Alloy Piping For Offshore Application
2.3 VIETNAMESE STANDARDS
CONTRACTOR / VENDOR shall be responsible for ensuring compliance with all applicable
codes, standards and regulations.
All materials are subject to VR (Vietnam Register) classification requirements.
2.4 CONFLICTS
CONTRACTOR or SUPPLIER shall advise COMPANY of conflicts between the specification,
data sheets and the referenced codes and standards. In case of any conflict, the most stringent
requirements shall apply.
3.0 PROCESS PIPING
3.1 PIPE DESIGN
3.1.1 General Requirements
o All piping shall be designed in accordance with API RP 14E, API RP 14C and ASME B31.3,
these specifications and other COMPANY Specifications unless otherwise noted.
o All sour service hydrocarbon piping systems shall be in accordance with NACE MR0175
“Sulfide Stress Cracking Resistant Metallic Material for Oil Field Equipment”.
o The selection of pipe, piping components and valves shall be in full accordance with
COMPANY Technical Requirements, including COMPANY “Piping Specification, Valve
Specification and Material Requirements” and in particular the appropriate Piping Material
Class Data Sheet for the intended service.
SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
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o The design, layout and support of Chlorinated Poly Vinyl Chloride (CPVC) piping systems
shall be in accordance to ASTM D2846, the manufacturer‟s requirements and
recommendations and the COMPANY Technical Requirements.
o The design, layout and support of Fiberglass reinforced plastic (FRP) piping systems shall be
in accordance to ISO 14962 and ASTM F1173 or D2996 or D2310, the manufacturer‟s
requirements and recommendations and the COMPANY Technical Requirements.
o A sufficient number of flanges or unions shall be provided in all piping to allow
disconnection of valves and equipment for maintenance and without the need to cut or
remove pipe supports.
o All turns on incoming flowline piping to production manifold headers shall be made with
target tees with solid end.
o Piping headers shall generally be terminated with flanges and shall be installed to allow for
future expansion of the header, if required.
o The design of skid assemblies shall be such that no pipe, instrument or other component
extends beyond a vertical plane connecting any two pad eyes.
o Unavoidable pockets to be reviewed with COMPANY to determine requirement for
automatic or manual drains.
o Piping shall be designed to minimize pockets and low points. Glycol return piping from
glycol contactors in systems which use glycol powered pumps shall not be pocketed such that
breakout gas would cause pump stalling.
o All service utility piping shall have at least 10% additional or spare takeoff points and be
terminated in such a manner as to facilitate extending the line at a later date.
o Bursting discs shall not be used unless the COMPANY provides specific written approval.
o Relief valve and burst plate piping shall be adequately supported to resist the forces generated
by the associated high fluid velocities.
o Any safety valve discharging into a closed relief / flare header should be arranged so that the
discharge pipe enters the header at 45º to the flow direction above the centerline of header for
branch sizes 4” and above. If the above arrangement is not possible, alternate arrangement
needs to be discussed with COMPANY as a case to case basis.
o Any safety valve discharging to the atmosphere shall be equipped with an outlet riser. A 8mm
diameter drain hole shall be provided in the lowest point of the outlet discharge.
SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
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3.1.2 Materials
Pipe, fittings and valves for service specified shall conform to COMPANY 2014-4800-1L-0007
“Piping Material Classes Specifications” and 2014-4800-1L-0006 “Valve Specification and
Material Requirements”.
3.1.3 Design Pressure
Operating pressure and design pressure for piping systems and pressure safety device set points
shall be determined and shall conform to API RP 14C and as specified on the P&ID. The design
pressure and operating pressure for the lines is specified in the process line list for ST-PIP, ST-
LQ and WHP-C.
3.1.4 Design Temperatures
The design & operating temperature of the lines are specified in the line list for ST-PIP, ST-LQ
and WHP-C. Design temperature downstream of a pressure safety valve (PSV), control valve, or
other pressure-reducing device shall include the temperature drop due to the Joule-Thomson
effect.
3.1.5 Loads
o Piping systems and supports shall be designed for lines filled with water for hydrostatic
testing at 210C, as applicable, apart from the criteria mentioned in Pipe Stress Analysis (Doc.
2014-4800-1H-0004).
o Piping systems on floating facilities shall be designed to meet specified motion criteria.
o Transportation and installation loads shall be considered in the design.
3.2 LINE SIZING
3.2.1 General Pipe Sizes
o Pipe sizes, 1¼-, 2½-, 3½-, 5- and 7-inch, shall not be used except with prior approval of
COMPANY. As a general rule, all run and rack piping shall be 2-inch minimum.
o If non-standard pipe sizes are part of purchased equipment, connecting pipe shall be
transitioned to the next standard size as soon as possible.
o Minimum pipe size shall be ¾-inch except for the following (where stainless steel tubing
shall be used):
Instrument drains and vents.
Instrument tubing lines.
Pressure gauge lines.
Sample lines.
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Chemical injection lines.
Rotating equipment components.
o Threaded connections are not allowed in hydrocarbon service. The bleed rings shall have SW
connection and a ¾” ball valve shall be welded to bleed ring with other end plugged. Bleed
ring taps be ¾” minimum.
o Minimum pressure rating for ¾-inch and smaller piping shall be 3000 psi.
o Weldolets, sockolets, elbolets, etc. shall not be used on forged steel fittings in hydrocarbon
piping, except for thermowell insertion points. Further exceptions shall be subject to prior
approval of COMPANY.
o Stainless Steel 317 tubing with formed bends and tubing fittings shall be used when sizes
smaller than ½” are necessary. Sizes in inch nominal sizes.
3.2.2 Fluid Flow Line Sizes
o Except for vent, flare, relief line and fiberglass reinforced piping, single and multi-phase fluid
piping shall be sized by the methods outlined in API RP 14E.
o Vent, flare and relief line piping shall be sized in accordance with API RP 521.
o Fiberglass reinforced pipe shall be sized for a fluid velocity not to exceed 4.6 m / sec.
o Line sizing calculations shall be submitted to COMPANY for review.
o Piping shall not be oriented diagonally in the horizontal or vertical plane without prior
approval of COMPANY.
o Piping running east and west shall have a minimum of 600 mm vertical separation
(BOP/BOP), or 200 mm clear (TOP/BOP) from piping running north and south, unless
otherwise approved by COMPANY.
o Bottoms of insulated lines regardless of temperature shall be supported on steel shoes.
3.2.3 Plated Deck Penetrations
o Shall employ seal welded deck penetration sleeves 75mm above deck and 25mm below deck.
o Shall have a minimum 25 mm gap between sleeve and pipe or sleeve and outside of
insulation.
o Where required deck/bulkhead penetrations shall be sealed with Calcium Silicate.
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3.2.4 Grated Deck Pipe Penetration Sleeves
o Shall be welded to grating prior to galvanizing.
o Shall extend 75 mm above and 25 mm below grating.
o Shall be either split or have a diameter large enough to permit passage of a flange for the
pipe.
o Grating shall be galvanized after installation of penetration sleeve.
3.3 LAYOUT AND CLEARANCE
o Piping shall be arranged to achieve the shortest and most efficient pipe runs imposed by
process logic and equipment layout.
o Piping arrangements around process vessels shall permit access to manholes and openings in
vessels with sufficient space to move davit supported covers out of the way.
o Piping design shall provide for servicing or removal of instruments, caisson mounted pumps,
pump casings, orifice plates, heat exchanger bundles, filter elements, compressor pistons and
rods and other equipment parts and appurtenances. The use of removable pipe spools to
provide access must be approved by COMPANY.
o Layout shall allow for equipment staging areas near cranes on each deck.
o Piping design shall consider the following safety concerns:
Crane lifts and other logistical operations over piping/vessels.
Marine operations around pipeline and flowline risers.
Accommodation and muster areas with special attention to pipeline and flowline risers.
Direct fired equipment, engine and turbine exhausts and potentially hazardous mechanical
equipment in vicinity.
Local atmospheric vents, blowdown and relief of hydrocarbons relative to platform
orientation, potential ignition sources, seasonal wind directions, helicopter flight paths
and building air intakes.
o Piping straight length upstream and downstream for flow elements shall be as per ISO 5167
for Beta ratio 0.7 or Vendor recommendation. If not possible, straightening vanes to be
provided with suitable upstream and downstream lengths.
3.3.1 Accessibility
o Access to equipment valves and instruments shall be provided for operation, disassembly and
removal.
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o Control valves shall be located so as to allow the reading of the control indicator. Relief
valves, shutdown valves and lubricated valves shall be easily accessible and located such that
valves may be serviced.
o Except for drain and vent valves used solely for construction and start-up purposes, access to
valves, controls and instruments shall be provided from deck level by means of ladders
stairways, walkways, or elevated landings.
3.3.2 Chainwheels and Extension Stems
o Shall require COMPANY approval.
o Shall be kept to a minimum.
o Shall be restricted to areas where impractical to install an elevated walkway or landing.
o Shall clear deck or walkways by 1 meter.
o Shall be fitted with safety cables to prevent chain wheels from falling to the deck.
3.3.3 Gauge Glasses, Temperature Indicators and Pressure Gauges
o Shall be visible from deck or skid edge.
o Shall be visible from related control instruments.
o Temperature indicators and pressure gauges not associated with control loops shall be located
such as to be visible from normal operating levels.
o Process sampling and drain connections shall be accessible from deck or elevated platform.
o Drain and sampling effluent shall be captured by the open drain system by tubing to drain or
skid pan.
3.4 CLEARANCE
The following minimum clearances shall be provided, unless otherwise specifically approved by
COMPANY:
Application Clearance from Bottom of Pipe or
support or Bottom of Insulation to Deck
Personnel access, overhead (including
bottom of associated pipe supports) 2250 mm
Lines at grade or deck elevation 450 mm
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o A minimum of 25 mm clearance, including insulation and flanges, shall be provided between
adjacent piping runs.
o Pipe spacing and bottom elevation shall take into account insulation thickness and movement
due to thermal expansion or contraction.
o Minimum clearance of 600mm shall be allowed above and below orifice flanges to allow for
instrument piping
o Lines with orifice meter assemblies shall have sufficient clearance for installation and
removal of orifice plate.
For further details on clearances, refer Layout Philosophy & Design Constraint Document (2014-
4800-1H-0002).
3.4.1 Clear Passageways
o Passageways for personnel access and movement and designated escape or evacuation routes
shall be unobstructed and a minimum of 1200mm wide for primary escape route with the
overhead clearance of 2200 mm. As far as possible these access routes shall be kept straight
with minimum turns.
o Low elevation piping and/or pipe stiles shall not be permitted in designated escape or
evacuation routes. Low elevation piping in other passageways may only be used with specific
COMPANY approval. Pipe stile must be used.
3.5 THERMAL EXPANSION AND SUPPORT
General
Piping shall be designed with provision for thermal expansion and contraction in accordance with
ASME B31.3.
CAESAR–II Ver.5.30, shall be used to analyze Stress Critical piping when comprehensive
analysis is required.
The details regarding requirement of analysis involved in determining routing and support for the
piping shall be referred from Pipe Stress Analysis Philosophy 2014-4800-1H-0004 for further
requirement on the analysis.
Expansion Joints
Expansion joints in piping shall not be used to provide flexibility, except on engine or gas turbine
exhaust piping, or other special applications as identified by COMPANY.
Provisions for expansion, contraction or relative platform movement on bridge supported pipe
shall be by expansion bends or loops, or other COMPANY approved methods.
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3.6 COLD SPRING DESIGN
Cold spring design may be used only to reduce forces and moments resulting from thermal
expansion. Cold spring shall generally be avoided and shall be used only with specific approval
of COMPANY.
3.7 HANGERS AND SUPPORTS
General
o Design shall be in accordance with ASME B31.3 Chapter II, Part 5.
o Rigid supports are preferred.
o Pipe or equipment supports shall be arranged such that supports do not have to be cut out to
remove supported pipe or equipment.
o Support Design shall assume all pipes are filled with hydrotest water.
o Hangers and supports shall not interfere with the free expansion and contraction of piping
between anchors.
o All corners of pipe supports shall be rounded.
o If necessary, temporary supports shall be specified during erection or transportation to
prevent over-stressing pipe or equipment to which piping is being connected. Temporary
supports shall be indicated and markup on piping stress isometric drawing of stress analysis
report. All temporary supports are to be removed before the system is placed in operation.
Design of major temporary supports to be reviewed and approved by COMPANY.
o Piping shall be supported as necessary to prevent sagging, mechanical stresses and vibration,
as applicable. Piping should be supported on top of racks, stanchions or individual standoffs.
o Piping at valves or mechanical equipment requiring periodic maintenance shall be supported
so the item can be removed with a minimum necessity of installing temporary pipe support.
o In vibration services, such as piping to and from reciprocating compressors, u-bolts shall
have double nuts on each side
.
o U-bolts shall be Grinnell Figure 137 or approved equal and shall all have double nuts, these
shall be guide type or grip type as per support details.
o Special attention must be given to supporting fiberglass piping. For fiberglass lines, u-bolts
shall not be used. Only strap type clamps/supports are acceptable. FRP Vendor‟s design for
support type and span shall govern.
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o All pipe supports shall include a stand-off shim to prevent corrosion caused by metal-to-
metal contact between the steel pipe and support. The shim shall be fabricated out of an
insulating material such as neoprene, Teflon, micarta, etc.
o Pipe support locations & support tags shall be shown on the isometric drawings. For pipe
sizes less than 2” the support location and type shall be field verified. In addition, all weld
attached supports shall be shown on the isometric drawings.
o Pipe shoes may be weld attached or clamp type.
o Pipe larger than 2" shall not be supported from the side or above the pipe, without prior
COMPANY approval.
o All Insulated piping shall be supported by shoes with welded guides as required.
o Pipe support welds shall be detailed in accordance with AWS D1.1.
o Small instrument tubing and piping shall be continuously supported and protected with a
structural member or tray as described in the Instrumentation specification.
Refer to 2014-4800-13-0001 „Pipe Support Standard for ST-PIP, ST-LQ, WHP-C‟ for further
requirement and pipe support plan table.
3.8 ADJUSTABLE HANGERS
Lines that require an exact elevation may use adjustable hangers with COMPANY approval.
Adjustable hangers shall have:
o Rod threads engage full length of threaded portion of turnbuckle or adjusting nuts.
o Double adjusting nuts.
o Rods & nuts to be hot dip galvanized and carbon steel material.
o U - Bolts and nuts shall be Polytetrafluoroethylene (PTFE) coated or COMPANY approved
equal.
U - Bolts shall:
Be rubber coated over PTFE coated or approved equal.
Be fitted with 2 nuts each for locking purposes.
Extend 6.35 mm beyond the outer lock nut.
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3.9 ANCHORS AND GUIDES
General
o Anchors and guides shall be used only to prevent excessive misalignment, localized over-
stressing, or excessive forces or moments on equipment.
o Anchors and guides, if used, shall be located in accordance with pipe stress requirements.
o Steel sliding shoe or pad supports shall be provided to prevent abrasion of bare pipe and pipe
insulation.
o Length of shoe to be at least 100% longer than calculated axial movement of piping or 6
inches, whichever is the greater. Shoes may be welded or strap attached.
3.10 SPRING HANGERS
Spring hangers shall be used only where rigid supports shall be incapable to take care for
sustained loads during operating or design conditions. The spring hangers shall be designed case
by case as per the pipe stress analysis and the design data shall be issued to procurement. The
spring hangers shall be selected such that the percentage load variation shall be within acceptable
limits and the spring load shall be at middle of the spring hanger selection chart during cold
installation condition.
3.11 PROCESS DRAINS AND VENTS
3.11.1 Process Piping Drains
o Drain valves shall be installed between isolation valves where liquid may be trapped. Bleed
rings may be used for this purpose if a location is not otherwise available for a TOL or SOL.
o Low point process drains shall conform to the following minimum size connections:
Class Drain Size
2500# and Below ¾-inch
API 10000# 2-inch
o Operational low point drains in process service shall be piped with block valves to the closed
drain system.
o Drains emptying into open receptacles shall terminate 10mm above the top of the drain
receptacles and the discharge shall be visible from the location of the drain valve.
o Vent, relief, flare and gas compressor suction lines shall be designed to avoid low point liquid
traps. Unavoidable traps must be approved by COMPANY; an operational low point drain
shall be installed at low points.
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o Operational drains shall be shown on piping arrangements. High point vents and low point
drains used only for hydrotest shall be shown on isometric drawings.
o P&ID‟s shall be revised to include operational high point vents and low point drains after
completion of the piping design layout.
o Process Vessel Drains
Multiple drain valves on horizontal pressure vessels shall:
Be manifolded together.
Be connected to the closed drain system (this may be waived by COMPANY).
Have both ends of manifold blind flanged for clean out or local draining to skid pan.
o Vessel drain connections not connected to closed drain system shall have a blind flange with
a ¾-inch female tap (located at the bottom half of the blind flange) with valve and plug,
bolted to outside valve flange.
o In sandy service, additional sand clean outs may be specified.
o Flare lines shall have minimum 1:200 slope.
3.11.2 Vents
o High points of lines shall have ¾-inch minimum vent connections.
o Valved vents shall be installed where periodic vapor accumulation may be detrimental to
downstream equipment such as pumps and heat exchangers.
o Vents required during startup or operation shall be equipped with a valve.
o Vents required only for hydrotesting may be plugged without a valve.
o Frequently operated vents shall be piped to the process vent system.
3.11.3 Plugs
o Drain and vent valves not piped to specific locations shall be plugged, capped or blind
flanged, as appropriate.
o Plugs for threaded drain and vent valves shall be as per piping material specification.
3.12 CLOSED DRAIN SYSTEM
Closed drain system shall:
o Be segregated from open drain and deck drain systems.
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o Gather pressurized process vessel drains, low point drains and operational drains.
o Convey fluids to a closed drain sump tank in the most efficient manner practical. Where
installation of a separate closed drain sump is not practical, the L.P. Flare scrubber, or other
suitable vessel may be used with COMPANY approval.
o Closed drain headers shall not be sized to maintain a flushing velocity. They shall be run flat
or turned continuously down, if possible.
o Drainpipe shall have a uniform slope of 1:200 (ABS Building & Classing Facilities on
Offshore Installations Ch. 3, section 13.3.2) and avoid sags. Where not practical, process
drain lines may be pocketed and drained vessel pressure may be used to drive flow, with
COMPANY approval. Pockets shall be provided with valved drains.
o To prevent overpressure outlets of closed drain system shall not have block valves.
3.13 STRAINERS
3.13.1 Temporary and Permanent Strainers
o Temporary and permanent strainers shall have net open area equal to or greater than 150% of
cross sectional area of inline piping.
o Suction lines to rotating equipment (compressors, pumps, etc.) shall have temporary or
permanent strainers.
o Temporary strainers shall be sited at a removable spool to allow for ease of removal and
replacement.
3.13.2 Temporary Strainers
o Temporary strainers shall be provided upstream of pumps, plate heat exchangers, control
valves with noise abatement trim and other items subject to plugging.
o Piping shall be arranged to permit removal of temporary strainers from flanged joints without
altering pipe, pipe supports or equipment alignment. It is recommended that strainers be
situated at the last bend to allow for ease of removal and replacement. (Final configuration to
determined during detail engineering and subject to COMPANY approval)
3.13.3 Permanent Strainers
o Piping normally carrying fluids containing materials detrimental to the operation of
instruments and equipment shall have permanent strainers upstream of instruments and
equipment.
o Permanent strainers shall be installed upstream of turbine or PD meters in produced liquid
service.
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3.14 VALVES
General
In general, the face-to-face dimensions of flanged valves NPS 24" and smaller shall conform to
ASME B16.10 and the flanges on steel flanged valves 24" and smaller shall conform to ASME
B16.5. Flanges on body on steel valves larger than 24" shall conform to ASME B16.47 Series A,
and its end connection shall conform to ASME B16.47 series A Raised face flanges shall
conform to ASME B16.5 having serrated-concentric or serrated-spiral finish. Oval ring joint
flanges with octagonal grooves conforming to ASME B16.5 shall be used for ASME class 900
and above. Weld end valves shall not be used without prior approval by COMPANY.
Valves shall be Manufacturer‟s standard pattern, wherever possible and shall be selected to meet
the necessary service requirements.
If piping specification changes at a valve, valve shall be rated for the higher pressure and
coincident temperature specification. Specification change shall be indicated on P&ID‟s.
The first process valve (root valve) from process piping header or vessel shall be ¾-inch
minimum consistent with section 3.2.1.
Unless otherwise approved by COMPANY, small valves shall not have bodies that screw apart.
Valve dimensions shall be identical to the dimensions specified in ASME B16.10, Face-to Face
and End-to-end Dimensions of Ferrous Valves, or API Spec 6D, Specification for Pipeline
Valves (Steel Gate, Plug, Ball, Check Valves). Face-to-face dimensions shall be long patterns,
unless approved by COMPANY.
All valves except check valves shall be capable of sealing with design pressure applied from
either end of the valve.
Unless otherwise specified, valves shall be suitable for oil, water and gas service throughout the
temperature range of the pressure class.
Valve pressure-class ratings 2500# and below shall be in accordance with ASME B16.5.
Valve pressure-class ratings API 10000# shall be in accordance with API 6A.
For testing of valves, API standard 598, Valve Inspection and Test, or API specification 6A and
6D, Pipeline Valves, shall be used as a basis.
Unless otherwise specified on the piping material classification data sheets, gate valves shall be
outside screw and yoke (OS&Y) with a rising stem, a bolted bonnet, a bolted packing gland and a
solid wedge gate.
Ball valves in process service shall be certified fire safe in accordance with API 607/API 6FA or
If resilient seat inserts are used, the inserts shall be capable of withstanding the maximum
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temperature encountered in the service application. Teflon or reinforced Teflon seat insert is
preferred.
The valves stem shall not be retained by the packing gland. A shouldered stem with bottom entry
is preferred.
Valves shall be identified in accordance with the approved P&IDs and the COMPANY
Specification 2014-4800-1L-0007, “Piping Specifications”.
Valves and specialty items shall be supplied with a 316 stainless steel tag attached to the gland
bolting or hand wheel with 316 stainless steel wire. The tag shall contain the applicable valve
identification tag number or specialty item number.
Valves designated as "LO","LC", "CSO", or "CSC" shall be provided with the capability of being
locked in either the fully open or fully closed position.
All steel, stainless steel and alloy Gate, Globe and Angle valves of ¾” and larger shall be of
Outside screw and Yoke design.
3.14.1 Valve Operators
o All manual valves shall be provided complete with hand wheel or lever operators as specified
in the Piping Valve Specification Tables located in COMPANY‟s 2014-4800-1L-0006
“Valve Specification and Material Specification”.
o Operating valves are to be accessible from the skid or walkway. If this is not practical,
ladders and platforms may be used.
o Manually operated valves located more than 2100 mm above operating platform or floor and
which are normally used in plant operations or in emergencies, shall be provided with
"Hammer-Type" chain wheels and chains. Valves located below the floor line, which are
normally used in plant operations, shall be provided with extension stems. Valves in these
categories shall be kept to a minimum.
o Gear operators shall be heavy-duty type and shall be completely housed in a weatherproof
enclosure. Any lubricant if required for the gear operator shall be suitable for winter
conditions and be specified by the COMPANY.
3.14.2 Ball Valves
o Except as specified on the P&ID‟s, ball valves shall be used for shutoff service, including
block valves on well manifolds and vents and drains in pressure classes through ASME class
2500 and API classes 5000 and 10000. These valves shall normally be reduced port.
Unless otherwise specified, full port ball valves shall be used in the following applications:
o Lines requiring pigging.
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o Horizontal lines sloped for continuous draining.
o Inlet and outlet of pressure safety valves (PSV‟s) and rupture disc (PSE‟s).
o Reduction of pressure drop where necessary to meet design criteria.
o On drain lines subject to potential blockage.
o Where the bore velocity would cause unacceptable pressure loss, noise, erosion, or exceed
supplied specified limits for corrosion inhibitor film stability.
o In services that are prone to blocking.
o Full port valves shall be identified on P&ID‟s. Floating ball or Trunnion Mounted Ball shall
be referred to Piping Material Classes Specifications Doc. No. 2014-4800-1L-0007.
3.14.3 Butterfly Valves
o All Butterfly Valves shall be of the "Fully lugged" design so as the piping can be removed
from either side without releasing the valve.
o Butterfly Valves should generally not be used in produced fluid service but in a low pressure,
non-critical service if tight shutoff is not required.
o Butterfly Valves should only be used in ASME Class 150 service, unless they are not
required to provide tight shut off.
o Butterfly valves 8” and larger shall be gear operated, below 8” with locking lever.
o All Butterfly Valves should be high performance type with a metal to metal secondary seat.
3.14.4 Check Valves
The following shall apply for the use of check valves:
Application Check Valve
2-inch and larger Swing & Wafer
1-½-inch and smaller Lift (ball / disc / piston)
Centrifugal pumps Swing
Reciprocating pumps Piston
Centrifugal compressors Piston
Reciprocating compressors Piston
Check valves shall not be installed in the vertical with flow down.
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3.14.5 Globe Valves
Globe valves shall:
o Be used only where throttling is required.
o Not be used to provide tight shutoff.
o Be identified on P&ID‟s.
o Manual blowdown valves shall be specified as globe valves with ball valve.
o Bypass valves shall be globe valves, or as approved by COMPANY.
o All steel, stainless steel and alloy Gate, Globe and Angle valves of ¾” and larger shall be of
Outside screw and Yoke design.
3.14.6 Miscellaneous Valves
o Except for low-pressure service where ball valves shall be used, sample valves shall be
needle valves.
o Sample valves shall be located upstream of control valves.
o Generally chemical injection points should be located as far upstream in a piping run as
practical in order to maximize mixing.
o Weld end valves shall be inline repairable.
3.15 PRESSURE SAFETY VALVES (PSV)
Block Valves
o PSV‟s shall have an upstream and downstream (where required) full port block valve that
may be locked in either open or closed position or mechanical Interlock as per P & ID.
o Bleed and test valve shall be located between the upstream block valve and PSV:
¾” x ½-inch screwed needle valve for up to and including ASME class 600 sweet service.
¾-inch SW gate or ball valve for ASME class 900 and above sweet service and all sour
service.
o PSV‟s shall have a downstream full port block valve that will be locked in the open position.
Operational Requirements
o Where practical, PSV shall be mounted at higher elevation than relief header. If the PSV
must be located lower than the relief header, a drain line to the closed drain system will be
provided; this line shall have either a check valve or restriction orifice.
o PSV‟s in hydrocarbon service shall have spare relief valve, or other approved pressure
relieving device, sized for 100% system capacity such that one device may be taken out of
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service at any time without affecting the safety of the system. These shall be at all instances
of possible blocked discharge or gas blowby to a lower pressure rating specification.
Noncritical or spared equipment which can be taken out of service for PSV service may be
equipped with a single PSV.
3.16 PIPING TO PUMPS, VESSEL AND EQUIPMENT
3.16.1 Pump Piping
Pump suction lines shall be:
o Sized and arranged to meet pump NPSH requirements.
o Routed to pumps without creating vapor traps in line.
o Routed to flow continuously up or continuously down to the pump suction.
o Check valves in pump discharge lines shall be located between pump and first block valve.
o Piping at pumps shall have flexibility such that expansion or dead loads shall not impose
excessive strain on pump casings.
o If arrangement does not permit easy removal of pump, piping shall have removable spool
pieces. Flanged check valves or flanged fittings between discharge and suction block valves
and pump may be used in lieu of spool pieces.
o Pump casing and auxiliary drain connections on non-hydrocarbon pumps shall be piped to
open drain headers.
o Eccentric reducers on horizontal pump suctions shall be installed with top flat (TF).
o Sufficient maintenance and access space shall be provided around pumps. The minimum
maintenance width provided around pumps shall be 900 mm, except at the driver end where
the width shall be a minimum of 1 meter. Piping shall not obstruct the driver end of
horizontal pump skids under any circumstances.
o Where line size reduction is required at pump suctions, eccentric reducers shall be used to
eliminate vapor pockets, flat part of reducer on top (unless directed by a VENDOR to do
otherwise).
o For horizontal end suction centrifugal pumps, upstream piping shall be without elbows for at
least 5 pipe diameters.
o For all pumps taking suction out of a vessel or tank, the inlet block valves shall be full bore to
minimize suction piping pressure loss.
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o Pulsation dampeners shall be included on the suction and discharge of all reciprocating
pumps, unless approved otherwise by COMPANY in writing. The in-line type dampeners
shall be used, located as close as possible to the pump. Pulsation dampeners shall be
adequately supported so that pump flanges are not over-stressed.
o Seawater overboard lines shall be metallic pipes to prevent vibration damages.
3.16.2 Compressor Piping
o Suction and discharge piping of centrifugal compressors shall provide clearance for removal
of unit and pulling rotor with a minimum of pipe dismantling.
o Suction and discharge piping of reciprocating compressor shall be designed to eliminate (or)
otherwise minimize the effects of pulsation and vibration. Pulsation dampeners (or) bottles
shall be located as near as practical to the Compressor Cylinders.
o Piping shall not obstruct compressor, instrumentation and seal oil components.
o Lube oil return piping shall be sloped for gravity flow and have no pockets from the
compressor or turbine to the reservoir.
o Compressor piping from the inlet scrubber to the compressor case flange and the anti-surge
piping shall be made free from particulate matter, scale and rust by water blasting, pickling,
or other approved method. CONTRACTOR will provide his procedure for COMPANY for
approval. All lines to be so cleaned shall be identified on the P&IDs and also the isometrics.
o As a rule the section of piping to be pickled prior to start up is: all suction lines from the
scrubbers and the re-cycle lines back to the scrubbers.
3.16.3 Vessel Piping
o Vessel vents shall be piped to vent system.
o Distance between inlet and outlet nozzles on horizontal separators and surge vessels shall be
maximized.
o Piping layout and supports shall not interfere with access to vessel man-ways, gauge glasses,
primary level instruments and other facilities for operation and maintenance of units.
o Spectacle blinds shall be provided where indicated by COMPANY and shown on the P&ID‟s
and piping arrangement drawings. This is required where the manway to the vessel is large
enough to allow access.
o Unions shall not be located between pressure vessel and first block valve.
o Removable spools for ASME 900# - 2500# and API 1000# to be installed to all lines of 10”
and above that are attached to the vessel, if indicated in P&ID.
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o Piping may be supported from the Vessel but only if the supports were considered and
included in both the vessel design and fabrication.
3.16.4 Heat Exchanger Piping
o Exchanger orientation and piping shall provide for operating access and for maintenance
clearance for pulling the tube bundle, or rodding, or replacement of tubes with no or minimal
dismantling of piping.
o Cooling water shall be configured such that exchanger remains full of water during a water
supply failure.
o Gases shall be self-venting from exchanger.
o Valved drains and vents shall be provided on both sides.
o Valved chemical cleaning connections shall be provided as necessary.
o Process design shall consider relief requirements resulting from possible tubing leaks.
4.0 PIPING CONNECTIONS
4.1 GENERAL
o Hydrocarbon piping 2-inch and larger shall be of butt welded construction.
o Except for services described in section 4.3 pipe sizes 1½-inch and smaller may be screwed
or socket welded. Screwed or threaded connections limited to CL2500 and under, and socket
welded connections limited to CL300 and under, otherwise approved by COMPANY.
o Except where instruments may connect, pipe connections shall be ¾-inch minimum.
o Jackscrews or equal shall be provided for all ring type joint flanges 6” and above for ease of
piping or equipment removal. Jackscrews or equal shall be required at the spectacle blind or
spacer & blind location for all ring type joint flanges 6” and above , for easy removal.
4.2 BUTT WELD CONNECTIONS
Butt weld fittings for piping shall:
o Conform to ASME B16.9.
o Be as specified in 2014-4800-1L-0007 the particular class of service intended.
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Ells:
o Mitered ells shall not be used in pressurized piping
o Short radius ells shall be used only where space is limited and with prior approval of
COMPANY.
o Ells in wellhead flowlines upstream of manifold or first vessel shall be cushion tee type, if
indicated in the P&ID.
Bevels:
o Pipe ends for butt welding of pipe and fittings shall be beveled 30 degrees in accordance with
ASME B16.25 and as required by ASME B31.3.
o Pipe and fittings with wall thickness exceeding 22mm shall be beveled in accordance with
ASME B16.25, Fig.3. Except for API 10000 6BX flanges which are to be beveled according
to Fig. 9 in API 6A.
4.3 SOCKET WELD CONNECTIONS
General
Socket Welding is only allowed for piping classes CL150 and CL300 with piping size 1-½”NB
and smaller regardless of service.
Screwed or threaded connections are not allowed in the following services:
o Hydrocarbon service.
o Any service subject to vibration.
o Glycol service.
o Heating medium fluids.
o Steam.
o Lube oil systems.
4.4 FLANGE CONNECTIONS
4.4.1 Flanges for ASME Class 150 – 2500
o Shall conform to ASME B16.5 or MSS-SP-44.
o Shall be as specified in 2014-4800-1L-0007 for the particular class of service intended.
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4.4.2 Flanges for API 5000# and 10000#
o Shall conform to API spec. 6A.
o Shall be as specified in 2014-4800-1L-0007 for the particular class of service intended.
4.4.3 Flanges 26 inches and larger
o Shall conform to ASME B16.47 Series A or MSS-SP-44.
o Shall be as specified in 2014-4800-1L-0007 for the particular class of service intended.
o At the direction and / or agreement of COMPANY, proprietary end connectors such as
Techlok, Re-Flange, Graylok, or Taper Lok may be used to attain weight and space savings
as well as design flexibility.
4.4.4 Flange Faces
o Raised face (RF) flanges shall have smooth finish faces with a roughness between 125µinch
and 250µinch.
o Flat face (FF) flanges shall have rough finish faces with a roughness between 250µinch and
500µinch.
o Ring type joint (RTJ) flanges shall have smooth finish with groove roughness of max.
63µinch.
o Flanges mating with flat faced (FF) flanges, such as cast steel pump nozzles or fiberglass
flanges, shall be flat face type.
o Unless otherwise specified, flange bolt holes shall straddle normal horizontal and vertical
centerline of pipe.
4.4.5 Flange Bolts
o Stud bolts for ASME 150# – 2500# shall have a full continuous thread with the length of stud
bolts shall be in accordance with ASME B16.5.
o Stud bolts for API 5000# and 10000# shall have a full continuous thread with the length of
stud bolts shall be in accordance with API 6A.
o All flange bolts size 1-1/8” and larger shall have one bolt diameter extra length for hydraulic
tensioning.
o All bolts and nuts shall be coated with polytetrafluroethylene (PTFE) such as Stancote or
COMPANY approved equal.
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o Materials shall be as stated in the piping specifications.
o Stud bolts shall comply with ASTM A-193 (for material grade refer to piping materials
specification).
o Nuts shall comply with ASME A-194, (for material grade refer to piping materials
specification).
o Threads shall comply with ASME B1.1, Unified Inch Screw Threads (UN and UNR Thread
Form), with Class 2A tolerance for bolts and Class 2B tolerance for nuts.
o Nuts for bolts and studs shall be heavy hexagonal semi finished.
o Bolt thread compound suitable for the bolting material and service temperature shall be used
to prevent galling.
o For SS flanges, bolting shall comply with A320 Gr. L7/A194 Gr. 7L. For DSS flanges,
bolting shall comply with ASTM A453 Gr. 660 Class B. SS & DSS bolting on piping flanges
shall be PTFE Coated.
4.4.6 Weld Neck Flanges
o Weld neck flanges shall be preferred for all services.
o Weld neck bore shall match inside diameter of connecting pipe.
o Match boring may be allowed with prior permission from the COMPANY.
o Match boring shall be as per ASME B31.3
o Match boring of API flanges shall comply with API 6A dimensions.
4.4.7 Reducing Flanges
o These are not normally used but would be considered in extreme circumstances.
4.4.8 Slip-On Flanges
o Slip-on flanges may only be used in ASME class 150 service for appropriate piping systems
where space is limited. This provision is subject to COMPANY approval.
o Slip-on flanges shall be welded on front and back in accordance with ASME B31.3.
4.4.9 Flange Blinds
o Spectacle blinds, rather than spade-type blinds, shall be used.
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o Thickness of blinds shall be calculated in accordance with ASME B31.3.
o Blind flanges shall be in accordance with ASME B16.5.
o Spectacles, blanks and spacers shall be in accordance with ASME B16.48 and its thickness
shall be calculated in accordance with ASME B31.3. Minimum thickness shall be in
accordance with ASME B 16.48.
4.4.10 Flange Gaskets / Insulating Flanges
o Insulating flanges are not required according to MATERIAL SELECTION AND
CORROSION CONTROL REPORT FOR ST-PIP PLATFORM 2014-5981-MC-0001
paragraph 3.1.7. Galvanic Corrosion.
o CONTRACTOR shall ensure that the correct gasket material and thickness, as specified in
the Specification for Piping Design and Materials and on piping drawings, is used.
o Care shall be taken to ensure that the gasket and mating flanges are clean, true and free from
defects.
o CONTRACTOR shall ensure that the gasket does not, under any circumstance, protrude into
the bore of the pipe.
o When bolting flange joints with spiral wound gaskets, the gasket shall be compressed evenly
to the thickness of the guide ring. This would be equal to 25% to 35% compression of the
original gasket thickness (gasket compression shall be spot checked during bolt tensioning).
o Joint rings and gaskets shall not be re-used after dismantling.
o Full-face gaskets shall be used at flat face flange connections.
o Gaskets for RF and RTJ flanges shall be in accordance with ASME B16.20.
o Non-metallic gaskets for RF and FF flanges shall be in accordance with ASME B16.21.
o Flange gaskets shall meet the requirements for the service specified in 2014-4800-1L-0007
for particular class of service intended.
o Ensure hardness values of RJ Ring gaskets do not exceed the values of the RJ mating
grooves.
4.4.11 Flange Protectors
o Flanges inside splash zone area shall have flange protectors.
o Insulating flange gasket sets shall have a non-conducting flange protector.
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o Flange protectors for other than insulating flanges shall be 316 stainless steel.
o Flange protectors shall have grease nipple and shall be fully filled with grease after
installation.
4.5 THREADED CONNECTIONS
4.5.1 Materials
Swage and pipe nipples shall be in accordance with piping material specifications for the class of
service stated in 2014-4800-1L-0007.
Forged steel screwed fittings shall:
o Conform to ASME B16.11.
o Be in accordance with individual pipe specifications for the class service stated in 2014-
4800-1L-0007.
o Carbon Steel pipe nipples which support gauges, valves, or other devices shall be schedule
160 minimum. For stainless steel the pipe nipples shall be schedule 80S minimum.
o Square head plugs, threaded bushings, close thread (all-thread) pipe nipples and street ells
shall not be used.
o Swage nipples shall be used instead of threaded bushings.
o Threaded pipe connections shall have ASME standard pipe taper threads in accordance with
ASME B1.20.1.
4.5.2 Unions
Screwed piping shall incorporate unions for ease of removal of equipment.
Unions shall:
o Be kept to a minimum in pressurized hydrocarbon service.
o Be located on the low-pressure side of block valves.
o Not be installed between a pressure vessel and the first block valve.
4.5.3 Vibration
o Threaded piping shall be arranged such that vibration is minimized.
o Nipples, regardless of length, connected to a reciprocating pump or other equipment and
piping where vibration is anticipated, shall be securely braced.
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o Piping 1-inch and less shall have adequate support.
o Pipe racks with widely spaced pipe rack supports shall incorporate intermediate supports. On
pipe racks min. size to be 2”.
4.5.4 Branch Connections
o Branch connections are indicated on branch connection charts, which are included in the
piping specifications. This will be the preferred method of making branch connection. Any
deviations from this require approval of COMPANY Representative.
o Pipe to pipe connections (stub-ins) shall be used only with the approval of the authorized
COMPANY Representative and per the applicable code design criteria and reinforcing
requirements.
o Bushings shall not be used.
o Care shall be exercised in the detail design of small branch connections to prevent
mechanical damage or breakage due to vibration or excessive force. Connections that may
require bracing include sample points, instruments, purges, thermal relief valves, corrosion
probes and vent and drain connections (particularly where double blocks and bleeds are
required). The bracing method shall be subject to the approval of the COMPANY‟s Project
Manager. Care shall be taken in the location of small connections in piping subject to thermal
movement.
5.0 UTILITY PIPING
5.1 SEAWATER, UTILITY WATER AND POTABLE WATER PIPING
5.1.1 Operational Requirements
o Seawater pumps and distribution system shall be designed to provide required flow rates and
pressures at the highest elevation specified on the platform.
o Seawater cooling water discharges that are returned to the sea via risers shall be provided with
siphon breakers and restrictive orifices, as the need arises, to facilitate temperature and flow
control in the cooling water system.
5.1.2 Seawater Lift
o Seawater pumps shall generally have pump suctions located at 10500 mm (HOLD 1) below
mean low water level (MLWL) with the open end of pump caisson 4500 mm (HOLD 1)
below pump suction.
HOLD 1: Pump location to be confirmed by pump vendor data in detail engineering stage.
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o Seawater pumps discharge piping.
Seawater pump discharge piping shall be arranged to permit disassembly and access by
lift equipment for pulling the motor, column pipe, lineshaft (if applicable) and pump.
Overhead piping shall be arranged to permit disassembly and access by lift equipment for
pulling the pump assembly.
5.1.3 Utility Water Stations
Utility water stations shall have:
o ¾-inch hose connections with ball valve and globe valve.
o 15 meter lengths of hose such that all working areas may be reached.
o Processes or utilities requiring potable water shall have a disconnectable pipe or temporary
hose connection. Permanent pipe connections to the potable water system shall not be
permitted.
o Potable water connections shall be provided to living quarters, sprinkler system, if applicable,
to flush seawater from the system after use.
5.2 UTILITY AIR AND INSTRUMENT AIR PIPING
5.2.1 Operational Requirements
o Instrument air supply and distribution piping systems shall be designed in accordance with
2014-4806-4L-0002.
Service or utility air systems shall be provided:
o To meet demands of pneumatic tools, pneumatic pumps and air starters.
o For cleaning.
o For backup supply to emergency control system.
o Where indicated by COMPANY.
o Branch connections shall have isolation valves immediately adjacent to air header or air
manifold.
o All air or gas line branch connections shall be taken off the top of the header as close as
possible to the user.
o Instrument air and gas headers shall be equipped with valved low point drains which are
easily accessible.
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5.2.2 Utility Air Stations
Utility air stations shall have:
o ¾-inch hose connections complete with ball valve and quick disconnect.
o 15 m lengths of air hose such that all working areas may be reached.
o Work buildings and designated working areas shall be provided with minimum of two utility
air stations.
5.3 HEATING MEDIA PIPING
Heating media and steam piping shall be insulated in accordance with 2014-4800-1L-0005.
5.4 FIREWATER SYSTEM
5.4.1 Operational Requirements
o Sprinkler and water spray system design and arrangement shall be in accordance with NFPA
Standard 13 and NFPA Standard 15, as applicable.
o Sizes of distribution mains, laterals and risers shall be calculated to provide required flow
rates and pressures for the highest point in firewater piping system.
o For vertical installed firewater pumps, pump suctions shall generally be located at elevations
10200 mm (HOLD 1) below mean low water level (MLWL) with open end of pump caisson
4800 mm (HOLD 1) below pump suction.
HOLD 1: Pump location to be confirmed by pump vendor data in detail engineering stage.
5.4.2 Firewater Pumps Discharge Piping
o Firewater pump discharge piping shall be arranged to permit disassembly and access by lift
equipment for pulling the motor, column pipe, lineshaft (if applicable) and pump.
o Overhead piping shall be arranged to permit disassembly and access by lift equipment for
pulling the pump assembly.
o Butterfly valves shall not be used as deluge valves.
o Lockable deluge isolation valves shall be installed to allow testing of the deluge valve
without deluging equipment.
o Each section of piping that can be isolated shall contain high point and low-point connections
for flushing and draining each section. A drain or vent valve shall be located immediately
downstream of the deluge valve.
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o Branch connections for deluge nozzles shall be attached to distribution header above header
pipe center. No connections shall be permitted on lower portion of the piping.
5.4.3 Firewater Piping Layout
o Firewater ring main shall be configured to take advantage of the natural protection afforded
by structural members, buildings and unclassified equipment or vessels.
o To benefit from the physical protection and fire protection provided by a flooded deck,
firewater ring mains and laterals on solid deck platforms shall be located below the deck that
requires firewater service.
o Cellar decks shall have firewater ring main and branches located below deck be accessible
from subcellar deck where accessible.
o Isolation and by-pass valves serving fire main and laterals shall be accessible from deck
level.
5.4.4 Firewater Stations
Firewater stations shall be:
o Located around perimeter of decks being protected.
o Placed to minimize personnel exposure to potential hazards.
o Supplied with fire hoses of sufficient length such that hazardous equipment and classified
areas may be served from two stations.
o Supplied with monitors where suitable.
5.5 DECK DRAIN SYSTEM
5.5.1 Operational Requirements
Deck drains shall have:
o 4-inch minimum drain connection.
o Integral 2-inch deep water seal.
o Strainer cover.
o Removable stainless steel debris collector and cleanout at each drain trough.
o Temporary screens with 3 mm wire mesh shall be placed under strainer cover.
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o Deck drainpipe headers shall be 4-inch diameter or larger.
o Drainpipe shall be designed and supported with a minimum uniform slope of 1:200.
Cleanouts shall be:
o Located on headers at the end of each header / sub header.
o Within reasonable access of personnel.
o In general 90-degree turns in drain headers shall be pipe tees with blind flanged cleanout
points oriented to access the downstream header segment.
o Branches shall be connected to mains with a minimum slope of 1: 200 wherever possible.
o Skid-mounted equipment shall have drip pan drains, 2-inch preferred, connected directly into
deck drainpipe system. Skid drip pan drains shall be equipped with water seal and strainer
cover.
o Design capacity of drain system shall handle the expected maximum rainfall rate for the area.
5.5.2 Deck Drain Layout
Facility deck drain system shall be segregated into the following sections with each system
terminating with a liquid seal in:
o Potentially hazardous areas.
o Safe or unclassified areas.
o Facility deck drain system shall have a minimum of one deck drain placed under, or adjacent
to, each deck mounted vessel handling hydrocarbons.
o Deck drains shall be located at low points in facility decks caused by structural deflections due
to heavy equipment or vessels.
o Liquid seals to prevent backflow of vapors shall be provided at either each open drain or
lateral serving drain line segments where line connects to downcomer.
o Open drain connections to skid mounted equipment with no local water seals shall be
configured to prevent vapor backflow.
o Grated drain troughs used to collect spills shall have a liquid seal at the low end to provide a
vapor barrier rather than using a water-filled trough.
o Equipment modules and other enclosures having floor drains shall be piped to deck drain
system with a valve at the module or enclosure and an air gap above the deck drain opening.
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o Deck drains under equipment module skids or enclosures shall not be located such that a dead
air space may permit accumulation of potentially explosive gas mixtures.
o Open drain troughs under equipment modules, skids or enclosures shall have open portion of
troughs covered with steel plate welded flush with deck to seal in hydrocarbon vapors.
o Piping incoming to sump tanks shall enter tank below liquid level to provide a liquid seal.
6.0 PIPING AND INSTRUMENT DIAGRAMS (P&ID’S)
6.1 DRAWING LAYOUT
P&ID‟s shall be arranged in a neat and logical manner with piping shown in most direct and
efficient layout. The following shall be adhered to as closely as practical.
o P&ID‟s shall reflect the general process flow left to right on each sheet with the sheets in
sequential order.
o Major process lines shall not flow from right to left.
o Process flow and various inter-connections of pipe shall represent the physical layout of the
process system as closely as practical.
o Initial layout of process vessels and equipment shall provide adequate space to add
instruments, controls and accessories as required.
o Drawings shall be kept legible and easy to interpret without resorting to miniature fonts to
show necessary information.
o Adequate space shall be provided for transferring equipment information to P&ID‟s.
o Equipment design data shall be collected as early as practical for inclusion in the drawings
consistent with the P&ID legend and drafting practices.
o Boundary edges for skid mounted vessels and equipment shall be shown with process and
utility connections shown terminating at the skid edge with the flange or pipe connection size
indicated.
o Process lines carrying associated gases and vapors shall be arranged across the top of the
process vessels and equipment, or at top of sheet, to include vent, relief and blowdown lines.
o Process lines handling liquids and two-phase flow shall be shown below the process vessels
and equipment, or at bottom of sheet.
o Adequate space across the top of the sheet shall be reserved for inserting equipment and
vessel title blocks and descriptions.
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o Process lines carried forward or backward to the next sheet shall carry line continuation
blocks.
Process lines not having a connection to a process vessel, equipment, or other process line shall:
o Not be shown on the drawing.
o Be identified on the previous sheet with a line continuation block identifying the sheet
number to which the line will be continued on.
o Line continuation block shall be shaped to indicate the direction of flow.
o Finalized P&ID‟s shall be of such quality as to permit shutdown reproductions to A3 size
without loss of detail, clarity or readability.
6.2 DRAFTING DETAILS
Vessel and equipment identification, instrument nomenclature, safety devices and safety analysis
and design shall conform to API RP 14C.
Vessel and equipment numbers shall comply with the prefix letters of API RP 14C.
Normal flow direction shall be shown on process and utility lines by arrowheads in the lines.
Arrows shall:
o Be placed at changes in line direction and into line intersections.
o Be placed at the line match point on the edges of the drawings if continued to the next or
previous sheet.
o Not be required if line continuation blocks have been used.
o Not be placed at intermediate points in lines unless arrows cannot be accommodated as
indicated.
o Arrows may be omitted only if arrows will interfere with other pipe, fittings, controls, or
instrument details.
o Process lines shall be shown either horizontal or vertical.
o Diagonal lines shall not be accepted except to emphasize a 45-degree lateral tie-in and then
only for a short segment to represent pipe fitting.
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o Line breaks shall, as much as practical, occur only in vertically crossing process lines with the
horizontal lines kept continuous. Line continuations shall not have large breaks across vessels,
equipment, or instrument/control assemblies.
o Location of pipe specification changes in the lines shall be clearly indicated on P&ID‟s, piping
arrangement and shop drawings.
o Flanged vessel connections shall be indicated by nominal pipe size (NPS).
o Process and utility lines shall be identified as described in section 7.2.
o Process vessels and mechanical equipment shall be represented on P&ID‟s as close to vessel
and equipment physical characteristics as practical without loss of detail or clarity and include
location of major process connections.
o Symbols, abbreviations and service designations on P&ID‟s shall be described on the P&ID
legend sheet.
o Service designations and abbreviations on the P&ID legend sheet not necessary to the
drawings may be removed if removal improves clarity or provides drawing space.
7.0 IDENTIFICATION SYSTEMS AND ABBREVIATION
7.1 SERVICE DESIGNATIONS
o The service designations shown in Table 1 shall be used in conjunction with the line
numbering system defined in Section 7.2.
7.2 LINE NUMBERING SYSTEM
o Each line on the P&ID‟s, piping arrangement drawings and isometrics shall be clearly marked
to denote:
Nominal line size.
Service designation.
Pipe material specification.
Line number.
Insulation class.
The following example illustrates the line numbering system:
12” - PV - D1 – XXXX – 1H1
Where:
12” = Nominal line size (12 in.)
PV = Line service (see Table 1)
D1 = Pipe material specification per 2014-4800-1L-0007 (see Table 3)
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XXXX = Unique line number. Refer to P&ID legend for line number allocation for each
service
1H1 = Insulation specification per 2014-4800-1L-0005
The above line numbering shall be shown in P&ID and other document, where the line would be
refered
7.3 STANDARD ABBREVIATIONS
Table 3 lists the standard abbreviations found in the body of this specification and the pipe
material data sheets. The abbreviations shall be employed in the course of the work, the pipe
design and the drawings.
TABLE 1: SERVICE DESIGNATIONS [PER P&ID LEGEND SHEET]
AI Instrument Air SC Steam Condensate
AU Utility Air ST Steam
AV Vacuum
UG Utility Gas
CI Chemical Injection
CO Carbon Dioxide (snuffing) WF Firewater
CF Fire Fighting Chemical WI Seawater Injection
WP Potable Fresh Water
DC Closed Drain WS Seawater Low Pressure
DO Open Drain WU Utility Water
DF Diesel Fuel WG Grey Water
WB Black Water
FF Foam Firefighting WC Cooling Medium
FG Fuel Gas
FH High Pressure Flare PF Process Fluid (Liquid and vapor)
FL Low Pressure Flare PG Process Gas
PL Process Liquid
GL Glycol PW Produced Water
HF Hydraulic Fluid
HY Hypochlorite Inhibitor
HM Heat Media
MT Methanol
LO Lube Oil
NI Nitrogen
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TABLE 2: STANDARD ABBREVIATIONS
ANSI
API
Appd.
Asb
ASME.
ASTM
Atm.
BBL
BE
BF
B.F.
BL.
B.O.P.
B-P
Brz
Bt.
B-T
BW
C
C-C
CI
CL
Cplg.
CS
CVA
c/w
CWP
A
American National
Standards Institute
American Petroleum
Institute
Approved
Asbestos
American Society of
Mechanical
Engineers
American Society for
Testing and Materials
Atmosphere
B
Barrel
Beveled End
Blind Flange
Bottom Flat
Black
Bottom of Pipe
Beveled End - Plain
End
Bronze
Bottom
Beveled End –
Threaded End
Butt Weld
C
Centigrade
Center to Center
Cast Iron
Center Line
Coupling
Carbon Steel
Adjustable Control
Valve (Flowline
Choke)
Complete with
Cold Working
Pressure
Ecc.
E-E
EF
E1.
Elect.
E11.
ESD
E.W.
Exh.
Exp.
Expl.
F
FA
Fab
F&D
FC
FC
Fcg
FCV
FE
FE
FF
FI
FIC
Flg.
FO
FQI
FR
FS
FSV
FT
FW
E
Eccentric
End to End
Electric Furnace
Elevation
Electrical
Elbow
Emergency Shutdown
Erector Weld
Exhaust
Expansion
Explosion
F
Farenheit
Flame Arrester
Fabricated
Faced and Drilled
Fail Closed
Flow Controller (as
applicable to
instrumentation)
Facing
Flow Control Valve
Flanged End
Flow Element (as
applicable to
instrumentation)
Flat Faced
Flow Indicator
Flow Indicating
Controller
Flange
Fail Open
Flow Indicating
Recorder
Flow Recorder
Forged Steel
Flow Safety Valve
(Check Valve)
Foot
Firewater
H.C.
Hd.
Hor.
Hdr.
Hex.
hp
HP
H.T.
Hvy.
ID
IN
Ind.
Instr.
Insul.
Jt.
JW
LAH
LAHH
LAL
LC
LC
LCV
LI
LLC
LO
LP
LR
Lrgr.
LSH
LSHH
LSL
LT
H
Hose Connection
Head
Horizontal
Header
Hexagon
Horse Power
High Pressure
Heat Treated
Heavy
I
Inside Diameter
Inch
Indicating
Instrument
Insulating
J
Joint
Jacket Water
L
Level Alarm High
Level Alarm High
Level Alarm Low
Lock Closed
Level Controller (as
applicable to
instrumentation)
Level Control Valve
Level Indicator
Liquid Level Control
Lock Open
Low Pressure
Long Radius
Larger
Level Sensor High
Level Sensor High
High
Level Sensor Low
Level Transmitter
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Dia.
Dim.
Disch.
Dk.
DP
D.P.
Dm.
Dwg.
MSS
MW
N.A.
NACE
NC
NDT
NFPA
No.
NO
Nod.
Noz.
NPS
NPT
OCS
OD
OH
O-O
OSHA
D
Diameter
Dimension
Discharge
Deck
Design Pressure
Differential Pressure
Drain
Drawing
M
Manufacturers
Standardization
Society of the Valve
and Fittings Industry
Man Way
N
Not Applicable
Sour Service
Normally Closed
Non Destructive
Testing
National Fire
Protection
Association
Number
Normally Open
Nodular
Nozzle
Nominal Pipe Size
National Pipe Thread
O
Outer Continental
Shelf
Outside Diameter
Open Hearth
Outside to Outside
Occupational Safety
and Health
Administration
GAL
Galy
GG
GJ
Gl.V.a,
GPM
Gr.
Graph.
G.V.a
P-T
Rad.
Red.
Rev.
RF
RO
Rtg.
RTJ
SAW
SC
Sch.
Scrd.
SDV
SE
SF
SJ
SMA
Smlr.
Smls.
SO
SPS
Sq.
SR
SS
S-S
SSV
G
Gallon
Galvanized
Gauge Glass
Ground Joint
Globe Valve
Gallon per Minute
Grade
Graphite
Gate Valve
P
Plain End - Threaded
End
R
Radius
Reducer
Revision
Raised Face
Restriction Orifice
Rating
Ring Type Joint
S
Submerged Arc
Weld
Sample Connection
Schedule
Screwed
Shut Down Valve
Screwed Ends
Semi-Finish
Solder Joint
Shielded Metal Arc
Smaller
Seamless
Slip On
Standard Pipe Size
Square
Short Radius
Stainless Steel
Seam to Seam
Surface Safety Valve
Sdd
Max.
MH
MI
MIG
Min.
Misc.
Mk.
MMS
TF
Thrd
TIC
TIG
TI
TOE
MLWL
T.O.P
TSE
TSH
TSL
TW
UV
V.a.
Vac.
Vert.
WE
Whd.
WN
WOG
WP
Wt
M
Maximum
Man Hole
Malleable Iron
Metal Inert Gas
Minimum
Miscellaneous
Mark
Minerals
Management Service
T
Top Flat
Threaded
Temperature
Indicating Controller
Tungsten Inert Gas
Temperature
Indicator
Threaded One End
Mean Low Water
Level
Top of Pipe
Threaded Small End
Temperature Sensor
High
Temperature Sensor
Low
Thermometer Well
U
Ultra Violet
V
Valve
Vacuum
Vertical
W
Weld End
Wellhead
Weld Neck
Water, Oil, Gas
Working Pressure
Wall Thickness
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Rev: D
Page No.: 44 of 47
P&ID
PAH
PAL
PC
PCV
PE
PI
PIC
Pl.Va.
Pldg.
Press.
PSE
PSH
psig
PSL
PSV
P
Piping & Instrument
Diagram
Pressure Alarm
High
Pressure Alarm Low
Pressure Controller
PCV Pressure
Control Valve
Plain End
Pressure Indicator
Pressure Indicating
Controller
Plug Valve
Plugged
Pressure
Pressure Safety
Element
Pressure Sensor
High
Pounds per Square
Inch Gauge
Pressure Sensor
Low
Pressure Safety
Valve
S
SCSSV
Std.
Std.WT.
Stl.
Str.
Suct.
SWOE
TAH
TAL
TBE
TC
T-C
TCV
Temp.
Subsurface Safety
Valve
Standard
Standard Weight
Steel
Strainer
Suction
Socket Weld One
End
T
Temperature Alarm
High
Temperature Alarm
Low
Threaded Both Ends
Temperature
Controller
Threaded and
Coupled
Temperature Control
valve
Temperature
XS
XXS
X
Extra Strong
Double Extra Strong
SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
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Rev: D
Page No.: 45 of 47
TABLE 3: PIPING SYSTEM SPECIFICATION
Table or
Class
No.
Pressure
Rating & Code
Compliant
Piping Base Material Services
A1
ASME 150 RF
(3 mm C.A.)
ASME B31.3
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B
DC, DF, DO, FG, FH,
FL, GL, PF, PG, PL,
PW, MT, NI, UG, VA,
WS, WU, CF, FF
A1N
ASME 150 RF
(3 mm C.A.)
ASME B31.3
NACE
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B
DC, FG, FL, PL, MT,
VA, FH
A2
ASME 150 RF
(3 mm C.A.)
ASME B31.3
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B (High Temp)
HM, PF, SC, ST, DO,
VA, WB, WU, WF
A3
ASME 150 RF
(3 mm C.A.)
ASME B31.3
Low Temp. Carbon Steel, ASTM
A333 Gr. 6 or A671Gr. CC65 FH ,FL
A4
ASME 150 RF
(3 mm C.A.)
ASME B31.3
Galvanized Carbon Steel, ASTM
A106 Gr B or API 5L Gr. B VA, WB, WG, WU
A6
ASME 150 RF
(0 mm C. A.)
ASME B31.3
Stainless Steel, ASTM A312 Gr.
TP316/316L
AI, AU, CI, DF, FH,
FL, LO, PL, VA, WS,
DO, MT, CF, FF
A6N
ASME 150 RF
(0 mm C. A.)
ASME B31.3
Stainless Steel, ASTM A312 Gr.
TP316/316L
AI, AU, CI, DF, FH,
FL, LO, PL, VA, WS,
DO, MT
A7
ASME 150 FF
(0 mm C. A.)
ASME B31.3
ASTM D2846, CPVC 4120 F-441 HY, VA , WP
A8
ASME 150 FF
(0 mm C. A.)
ASME B31.3
Reinforced thermosetting Resin
FRP. ISO 14692
SW, AI, AU, DO, WF,
WP, WS, WU, VA,
WB, WG
A9
ASME 150 FF
(0 mm C. A.)
ASME B31.3
Seamless Cu/Ni 90/10 to EEMUA
144 condition „O‟ (annealed)
PW, WS, WF, WS, WU,
AU, DC
B1
ASME 300 RF
(3 mm C.A.)
ASME B31.3
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B
DC, FG, FH, GL, PG,
PL, WS
B1N
ASME 300 RF
(3 mm C.A.)
ASME B31.3
NACE
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B PL,PG
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Page No.: 46 of 47
Table or
Class
No.
Pressure
Rating & Code
Compliant
Piping Base Material Services
B2
ASME 300 RF
(3 mm C.A.)
ASME B31.3
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B (High Temp) DC, PG, PL, PW, HM
B6
ASME 300 RF
(0 mm C.A.)
ASME B31.3
Stainless Steel, ASTM A312 Gr.
TP316/316L FH, FL, FG
B8
ASME 300 FF
(0 mm C. A.)
ASME B31.3
Reinforced thermosetting Resin
FRP. ISO 14692
SW, AI, AU, DO, WF,
WP, WS, WU, VA,
WB, WG
D1
ASME 600 RF
(3 mm C.A.)
ASME B31.3
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B
DC, FG, FL, PF, PG,
PL, WI, WS
D1N
ASME 600 RF
(3 mm C.A.)
ASME B31.3
NACE
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B PL,WS, NI, PF, VA
D2
ASME 600 RF
(3mm C.A.)
ASME B31.3
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B (High Temp) DC, FG, PG, PL, WS
D3
ASME 600 RF
(3 mm C.A.)
ASME B31.3
Low Temp Carbon Steel, ASTM
A333 Gr. 6 or A671Gr. CC65 FH
D6
ASME 600 RF
(0 mm C. A.)
ASME B31.3
Stainless Steel, ASTM A312 Gr.
TP316/316L FH
D6N
ASME 600 RF
(0 mm C. A.)
ASME B31.3
Stainless Steel, ASTM A312 Gr.
TP316/316L FH
D11N
ASME 600 RF
(3 mm C.A.)
ASME B31.8
CS, API 5L Gr X65, PSL2, Smls
and DSAW PL (Pipeline)
D12N
ASME 600RF
(0 mm C.A.)
ASME B31.3
NACE
Duplex Stainless Steel – UNS
S31803
DC, FG, PF, PG, PL,
PW
E1N
ASME 900 RTJ
(3 mm C.A.)
ASME B31.3
NACE
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. B
DC, FG, FH, GL, PG,
PL
E3
ASME 900 RTJ
(3 mm C.A.)
ASME B31.3
Low Temp Carbon Steel, ASTM
A333 Gr. 6 or A671Gr. CC65 FH
SU TU TRANG FULL FIELD DEVELOPMENT – PHASE 1
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Rev: D
Page No.: 47 of 47
Table or
Class
No.
Pressure
Rating & Code
Compliant
Piping Base Material Services
E6
ASME 900 RTJ
(0 mm C.A.)
ASME B31.3
Stainless Steel, ASTM A312 Gr.
TP316/316L FH
E6N
ASME 900 RTJ
(0 mm C.A.)
ASME B31.3 NACE
Stainless Steel, ASTM A312 Gr.
TP316/316L FH, PG
E12N
ASME 900 RTJ
(0 mm C.A.)
ASME B31.3
Duplex Stainless Steel -UNS
S31803 PG, PF, FH
F1N
ASME 1500 RTJ
(3 mm C.A.)
ASME B31.3 NACE
Carbon Steel, ASTM A106 Gr B
or API 5L Gr. X65. PG,FL
F6N
ASME 1500 RTJ
(0 mm C. A.)
ASME B31.3 NACE
Stainless Steel, ASTM A312 Gr
TP316/316L CI
G1N
ASME 2500 RTJ
(3 mm C. A.)
ASME B31.3 NACE
Carbon Steel, ASTM A106 Gr B,
Smls
API 5L Gr.X65
PG, PL, DC, FH
G6N
ASME 2500 RTJ
(0 mm C. A.)
ASME B31.3 NACE
Stainless Steel, ASTM A312 Gr
TP316/316L FH, PG
L6N
API 10000 RTJ
(0 mm C. A.)
ASME B31.3 NACE
Stainless Steel, ASTM A312 Gr
316/316L PG, FH
L12N
API 10000 RTJ
(0 mm C. A.)
ASME B31.3 NACE
Duplex Stainless Steel -UNS
S31803, Smls PG, PF, FH
L13N
API 10000 RTJ
(0 mm C. A.)
ASME B31.3 NACE
Carbon Steel, API 5L Gr.X65,
PSL2, Smls PG, FH