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GENERAL SPECIFICATION 3.04

GENERAL PIPING DESIGN

Chevron Offshore (Thailand) Ltd

0 PH Issued for Use 8/2001

A MLJ Issue for Review 6/2000

Rev. By Description Date Rvw'd Appv'd

TABLE OF CONTENTS

1.0 INTRODUCTION

1.1 Scope1.2 Exclusions1.3 Responsibilities1.4 Conflicts and Exceptions

2.0 MANDATORY CODES AND STANDARDS

3.0 GENERAL REQUIREMENTS

3.1 General3.2 Piping Design and Layout3.3 Valving3.4 Branches3.5 Pipeways and Racks3.6 Accessibility and Clearance3.7 Pipe Stress and Flexibility3.8 Cold-Spring Installations

4.0 PROCESS SYSTEMS AND EQUIPMENT

4.1 General4.2 Wellheads, Flowlines, Manifolds and Separation Systems4.3 Pressure Vessels4.4 Fired Heaters4.5 Heat Exchangers4.6 Pumps4.7 Compressors4.8 Erosion Monitoring4.9 Chemical Injection4.10 Sample Connections

5.0 UTILITY SYSTEMS

5.1 Fuel and Utility Gas5.2 Instrument Air5.3 Utility Air5.4 Cooling Water5.5 Lube and Seal Oil Systems

6.0 PRESSURE RELIEVING SYSTEMS

6.1 General6.2 Open Relief Systems6.3 Closed Relief Systems6.4 Conventional and Pilot Operated Relief Valves6.5 Thermal Reliefs6.6 Rupture Disks6.7 Flare Systems

7.0 FIRE PROTECTION SYSTEMS

7.1 Firewater Systems7.2 Foam Systems7.3 Carbon Dioxide (CO2) Systems

8.0 VENTS, DRAINS, FLUSHING AND CLEANING SYSTEMS

8.1 General8.2 Vent Connections8.3 Drainage Systems8.4 Flushing Systems8.5 Cleaning Systems

9.0 INSTRUMENTATION

9.1 General9.2 Flow Instruments9.3 Level Instruments9.4 Pressure Instruments9.5 Temperature Instruments

10.0 CONTROL VALVES

10.1 General10.2 Piping Sizes and Pressure Drop10.3 Station Arrangements

11.0 SPECIALTY ITEMS

11.1 General11.2 Blanks11.3 Strainers11.4 Drip Rings

12.0 SUPPORTS AND ANCHORS

12.1 General12.2 Support Design12.3 Materials12.4 Applications12.5 Spring Supports12.6 Dummy Supports

13.0 DOCUMENTATION REQUIREMENTS

13.1 General13.2 Piping Plans13.3 Elevations and Sections13.4 Details13.5 Isometrics

APPENDICES

I Mandatory Codes and StandardsII Government RegulationsIII Chevron Standards

GENERAL PIPING DESIGN GS 3.04REVISION 0

CHEVRON OFFSHORE THAILAND LTD AUG 2001

1.0 INTRODUCTION

1.1 Scope

This specification, in conjunction with the other Technical Requirements, defines the minimum acceptable requirements for the design, layout, support and flexibility of piping systems used in upstream oil and gas production facilities. This specification governs piping systems provided in accordance with API Recommended Practice 14E "Design and Installation of Offshore Production Piping" and ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping."

1.2 Exclusions

This specification does not apply to process design, line sizing or equipment layout; nor does it apply to piping material and component selection, or to piping fabrication, installation, inspection and testing.

1.3 Responsibilities

CONTRACTOR shall be solely responsible for providing complete and operable piping systems in full accordance with all applicable Industry Codes and Standards, Government Regulations and COMPANY Technical Requirements.

1.4 Conflicts and Exceptions

1.4.1 All conflicts between this specification, the other Technical Requirements, and the applicable codes and standards shall be submitted in writing to COMPANY for resolution.

1.4.2 Any and all exceptions to the Technical Requirements shall be submitted in writing to COMPANY for approval.

2.0 MANDATORY CODES AND STANDARDS

2.1 The primary codes governing piping systems provided under this specification shall be API Recommended Practice 14E "Design and Installation of Offshore Production Piping" and ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping."

2.2 The most recent issue of the codes and standards listed in Appendix I "Mandatory Codes and Standards" shall be considered as a part of this specification.

2.3 Special design allowances outlined in any of the codes and standards may not be used without written approval of COMPANY.

2.4 COMPANY "Safety in Designs" Manual (GO-590) shall be considered as part of this specification. CONTRACTOR shall refer to COMPANY "Safety in Designs"

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Manual regarding all safety concerns related to piping system design, layout, fabrication and assembly, such as valve accessibility guidelines, overhead clearance requirements and valve handwheel/stem position limitations.

3.0 GENERAL REQUIREMENTS

3.1 General

3.1.1 Piping systems and components, including design, layout, support and flexibility shall be in full accordance with API RP 14E "Design and Installation of Offshore Production Piping," ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping" and COMPANY Technical Requirements. All addenda issued through the date of the Purchase Order, Contract or Agreement, as applicable, shall apply in full.

3.1.2 The selection of pipe, piping components and valving shall be in full accordance with the Technical Requirements, including General Specification 3.00 "Piping Service Classifications and Material Requirements," and in particular the appropriate Material Class Data Sheet for the intended service. Substitution of alternate materials or components shall require prior written approval by COMPANY.

3.1.3 The design, layout and support of Polypropylene Lined (PPL) carbon steel piping systems shall be in accordance with ASTM F492 "Propylene and Polypropylene (PP) Plastic-Lined Ferrous Metal Pipe and Fittings," the manufacturer's requirements and recommendations and the Technical Requirements.

3.1.4 The design, layout and support of Fiberglass Reinforced Plastic (FRP) piping systems shall be in accordance with the manufacturer's requirements and recommendations, and the Technical Requirements. CONTRACTOR shall note that the Technical Requirements do not include complete, detailed design, layout, support or flexibility requirements specific to the needs of FRP piping systems. CONTRACTOR shall be responsible for developing piping design and layout requirements to the mutual satisfaction of COMPANY and the FRP piping manufacturer.

3.1.5 The design, layout and support of Chlorinated Poly Vinyl Chloride (CPVC) piping systems shall be in accordance with ASTM D2846 "Chlorinated Poly Vinyl Chloride (CPVC) Plastic Hot and Cold Water Distribution Systems," the manufacturer's requirements and recommendations, and the Technical Requirements.

3.1.6 References in this specification to ANSI Class 150, 300, 600, 900, 1500 and 2500 flange ratings refer to ANSI B16.5 "Pipe Flanges and Flanged Fittings." References to API 3000, 5000 and 10,000 pound flange ratings refer to API 6A "Specification for Wellhead Equipment."


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3.1.7 All sour service hydrocarbon piping systems shall be in accordance with NACE MR-01-75 "Sulfide Stress Cracking Resistant Metallic Material for Oil Field Equipment."

3.2 Piping Design and Layout

3.2.1 CONTRACTOR shall be responsible for all piping design and layout, ensuring that it is suitable for the intended service and is in accordance with the Technical Requirements. Piping and equipment shall be arranged to maximize safety and operator accessibility. Piping, valves, instruments, etc. that protrude into walkway areas at or below minimum elevations as defined by COMPANY's "Safety in Designs" shall be rerouted.

3.2.2 Piping shall be routed in the true vertical or horizontal plane unless specified otherwise, and generally parallel to column rows. Diagonal and skewed angle piping runs shall not be accepted without specific COMPANY approval. For major piping runs, changes in direction shall coincide with changes in elevation. Care shall be taken not to create unnecessary low point liquid pockets or high point vapor traps.

3.2.3 Piping shall be routed to minimize run lengths and fitting quantities, while still providing adequate expansion and flexibility in the design. The number of flanged joints in hydrocarbon service shall be kept to a minimum.

3.2.4 Similar equipment and piping shall be grouped together to simplify the piping layout and ease operation and maintenance.

3.2.5 Piping shall not be routed directly above mechanical equipment such as pumps or compressors, or above operating or maintenance areas of process equipment. Piping runs shall be to the front, side, rear or beneath such equipment to facilitate operation and maintenance. Areas reserved for pulling of heat exchanger bundles and compressors shall be free of overhead piping. Piping shall not be installed below the lowest deck level unless absolutely necessary due to its service or route to or from a lower area, such as a boatlanding or pump caisson.

3.2.6 Valves and piping components requiring operator attention or regular servicing shall be accessible from deck level, unless specified otherwise by COMPANY. If not accessible from deck level, an elevated access platform shall be provided for operation and maintenance. Specifically, all control valves, relief valves, and meter runs shall be accessible from deck level or access platforms. Control valves shall be grouped at centralized operating locations, if practical.

3.2.7 Piping shall be arranged for easy removal of equipment for inspection, servicing and maintenance. Maintenance areas shall be clearly designated as such and free of piping runs.


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3.2.8 Prefabricated piping shall have a sufficient number of properly located field welds to allow flanged connections to be installed without imposing excessive strain on the equipment or piping.

3.2.9 Piping carrying caustic materials, chemicals, acids, or similar substances shall not be located near equipment or other piping with temperatures exceeding 200°F.

3.2.10 All piping connections in systems for corrosive service (polypropylene lined piping) shall be flanged. Threaded connections and unions shall not be permitted.

3.2.11 Hot and insulated lines shall be grouped together and separated from cold lines to control corrosion, condensation an vapor problems.

3.2.12 If practical, high temperature and high pressure lines shall not be located close to potential sources of electrical sparks such as electrical conduits, electrical trays, electrical connections, and motor operated equipment such as valves.

3.2.13 Hot materials shall not be discharged into open drains located near electrical runs.

3.2.14 The minimum spacing between circumferential weld joints shall be 2", or 6 times the wall thickness of the pipe, whichever is greater, unless otherwise approved by COMPANY.

3.2.15 Flange bolt holes shall straddle normal horizontal and vertical center lines.

3.2.16 Mitered joints and welds shall not be acceptable without written COMPANY approval.

3.3 Valving

3.3.1 The centerline of valves shall not be more than 11'-0" above an operating level or platform without COMPANY approval. Valves in which the center of the handwheel is 6'-0" or more above an operating level shall be provided with chain operators or extension stems. Chain drop shall normally clear operating platforms by 3'-6". Chain operators shall not be acceptable on valves 2" NPS and smaller. Access platforms are preferred to chain operators.

3.3.2 Valves shall not be installed with the stems inclined below the horizontal plane without COMPANY approval. Horizontally positioned valve stems shall not be located in the face hazard zone, which is defined to be between 4'-6" and 6'-3" above the deck or operating platform.

3.3.3 Special consideration shall be given to valves 10" NPS and larger with handwheels positioned horizontally, i.e. vertical stems. The handwheel shall not be located more than 4'-0" above the deck or operating platform. As an


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alternative to an additional platform, a gear operator with the handwheel in the vertical plane may be provided. In this case, the centerline of the handwheel shall not be more than 6'-3" above the deck or operating platform.

3.3.4 Valves that require operation during an emergency shall be easily accessible or shall be equipped with remote operating devices with convenient local control.

3.4 Branches

3.4.1 Branch connections in utility services shall be located at the top of the header. Branch connection root valves shall be located in the horizontal section of the branch, close to the header.

3.4.2 Branch connections in process services shall be located at the top or side of the header.

3.4.3 Header branch line block valves shall be located to allow complete drainage on each side of the valve.

3.4.4 Branch connections 2" NPS and smaller shall be equipped with break flanges in the following services:

• Chemical, quench, purge and steam injection into process lines• Flushing services

The break flanges shall be placed outboard of the branch block valve. A flanged branch valve shall be acceptable in lieu of break flanges.

3.4.5 For screwed or socket welded utility services, a union shall be provided immediately outboard of branch block valves unless the valves are flanged.

3.4.6 Compressed air line branches shall be provided with a full size opening arranged to allow system cleaning by blowing down pressure.

3.4.7 Couplings or other weld-on type branch connections and fittings shall not be located on a weld joint.

3.4.8 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 block and bleeds are required). The bracing method shall be subject to approval by COMPANY.

3.4.9 Care shall be taken in the location of small connections in piping subject to thermal movement.


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3.5 Pipeways and Racks

3.5.1 Where pipeways and racks are provided, utility and service lines shall generally be placed on the top level, and process lines on the lower level. Where process lines run to higher elevations, they may be located on the top level. On single level racks, utility and service lines shall generally be grouped separate from process lines.

3.5.2 The outer edges of pipeways and racks, whether double or single level, shall be allocated to heavy (liquid) lines and large diameter piping. The center of pipeways and racks shall be allocated to light (gas or vapor) lines and small diameter piping.

3.5.3 Process lines shall be placed on the same side of the pipeway and rack as the equipment they service when possible.

3.5.4 Pipe entering or exiting pipeways and racks shall roll out with a change in elevation so as not to block adjacent pipe slots.

3.5.5 Pipeways and racks shall be oversized by 25% during initial layout based on linear width. The "Approved for Construction" layout shall include a minimum of 15% spare space (oversized) based on linear width.

3.5.6 Expansion pipe loops shall be installed over the top of pipeways and racks. Loops shall not extend horizontally past the pipeway or rack edges without COMPANY approval.

3.6 Accessibility and Clearance

3.6.1 Piping shall be routed to avoid creating overhead interferences and tripping hazards. Overhead piping shall provide a clearance of 6'-8" at all platforms, walkways, egress routes, styles, etc., and 7'-0" at all stair treads as a minimum.

3.6.2 If possible, the difference in elevations between lines running platform north/south and those running east/west shall be a minimum of 2'-0".

3.6.3 Horizontal clearance between piping and equipment or major structural members shall be 12" minimum. A minimum clearance of 18" shall be provided between piping and equipment or other obstructions in areas requiring occasional access.

3.6.4 The center-to-center spacing between piping shall be governed by the flange diameters, insulation requirements, and thermal expansion characteristics of the piping. The clearance between piping, including flanges and/or insulation, shall be 1" minimum.

3.6.5 Piping arrangements shall provide sufficient operating space for maintenance equipment such as bridge cranes, monorail hoists and hook hoists, and shall not infringe upon designated walkway, access and laydown areas.


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3.6.6 Piping systems shall be constructed with unions or flanged joints wherever disassembly may be required. Piping that requires frequent servicing shall be arranged to preclude unnecessary removal of equipment, parallel piping or installation of temporary supports.

3.6.7 Sufficient breakout unions and flanges shall be provided for servicing equipment, in-line instrumentation, valves and piping components.

3.6.8 On installations with long runs of pipe, a longitudinal clearance shall be provided between pipes leaving the pipeway or rack to accommodate thermal expansion.

3.7 Pipe Stress and Flexibility

3.7.1 Thermal and mechanical expansion/contraction of piping systems shall be considered in accordance with ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping." Pipe loops or offset legs shall be utilized to provide flexibility for piping systems subject to expansion/contraction. Mechanical expansion joints, namely bellows type joints shall not be provided without COMPANY approval.

3.7.2 The piping arrangement shall provide sufficient support and changes in direction, pipe loops, anchors, spring supports and/or expansion joints to ensure that stresses are within the limits allowed by ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping" and the Technical Requirements. CONTRACTOR shall consider stresses resulting from static and cyclic movement of piping, vibration, and mechanical and thermal shock that may be encountered throughout the service life of the piping installation.

3.7.3 The criteria for determining whether or not to perform a stress/flexibility analysis shall be approved by COMPANY. As a minimum, a detailed stress/flexibility analysis shall be provided for the following services:

a. Centrifugal compressorsb. Reciprocating compressors rated at 200 HP and higherc. Centrifugal pumps with a 6" NPS or larger nozzle


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d. Centrifugal pumps operating above 1800 rpme. Piping installed on bridgesf. Services operating at 200°F and higherg. Services operating at 40°F or lower

3.7.4 When piping stress analysis is performed, it shall ensure that the pipe work complies with ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping" and the Technical Requirements, including:

a. The calculated stress (sustained, expansion, and occasional) complies with ANSI B31.3 allowables.

b. The applied forces and moment on flanged joints are within the limit allowed by the applicable code or Technical Requirement.

c. The applied forces and moments on hub connectors are within the manufacturer's allowable limits.

d. The fatigue life is acceptable.

e. Reactions at pipe restraints or anchors are available for support design.

3.7.5 Calculations to determine piping flexibility and expansion stress shall be based on the greater of the following temperature differentials:

• Difference between the minimum ambient operating temperature of the installation and the design temperature.

• For steam traced lines, the difference between the minimum ambient operating temperature and the temperature of the saturated steam reduced by 50°F.

3.7.6 If the piping stress analysis is performed with a computer program, the stress range reduction factor (f) used to calculate the allowable displacement stress range (SA) shall be in accordance with ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping," as applicable. The factor (f) shall be 0.7 for calculating SA when using a less rigorous methods of stress analysis.

3.7.7 The stress intensification factor for piping branch connections made by an integrally reinforced fitting, such as a weldolet, shall be in accordance with ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping" for unreinforced fabricated tees.

3.7.8 Thermal expansion shall be considered in the design of nonmetallic (CPVC) piping systems. The design expansion rate shall be 1/2" per 10°F change in temperature per 100' of length.

3.7.9 When spring hangers are utilized, accurate weight balance calculations shall be made to determine the required supporting force at each hanger location.


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3.7.10 The maximum stress in a piping system during hydrostatic testing shall not exceed 90% of the specified minimum yield strength (SMYS) of any pressure containing piping component.

3.7.11 Care shall be taken in designing and locating anchors and guides so as not to cause excessive stress by severely restricting the movement of the piping.

3.7.12 Lines that require expansion loops or offset legs shall be grouped together to minimize the cumulative space required by the loops.

3.7.13 The weight of the pipe at each equipment connection shall be accurately calculated to quantify the loads and moments imposed on the equipment.

3.7.14 Loads and moments exerted by piping systems at the flanges of mechanical equipment (such as pumps and compressors) shall not exceed the permissible reactions specified by the equipment manufacturer or the applicable industry standard, as modified below, whichever is more conservative. Applicable industry standards and permissible limits shall be as follows:

Equipment Type (standard): Permissible Limits:

Centrifugal Pumps(API STD 610)

In accordance with API STD 610 formulas

Centrifugal Pumps(ANSI B73.1, ANSI B73.2)

75% of the value calculated by API STD 610 formulas

Reciprocating Pumps(API STD 674)


Gas Turbines(API STD 616)


Centrifugal Compressors(API STD 617)

In accordance with NEMA SM 23 with constants in the formulas increased by a factor of 1.85

Reciprocating Compressors(API STD 618)

In accordance with API STD 618 formulas.

Steam Turbines(NEMA SM 23, API STD 611, API STD 612)

In accordance with NEMA SM 23 formulas

3.8 Cold-Spring Installations

3.8.1 Cold-sprung piping installations shall be acceptable only if approved by COMPANY.


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3.8.2 Cold-springing of piping will be considered only for piping that must be strain free at operating temperatures, or if a cold-spring installation is necessary to provide for lateral clearances in closely spaced groups of lines.

3.8.3 Cold-spring of more than 1/2" shall not be permitted.

3.8.4 Cold-sprung installations shall not be acceptable at rotating machinery under any circumstances.

4.0 PROCESS SYSTEMS AND EQUIPMENT

4.1 General

4.1.1 Piping terminations at pumps, compressors and other equipment shall be designed to prevent excessive loads, moments and stress on the equipment flanges. The piping shall be permanently supported to ensure that mating flanges are parallel, concentric and in contact prior to bolting the piping in place.

4.1.2 Suction and discharge piping to rotating and reciprocating equipment shall be designed to facilitate alignment of the equipment.

4.1.3 Piping headers with flanged ends shall be located so that future extension of the header is not blocked by adjacent piping or equipment.

4.1.4 Deadlegs in process piping shall be avoided whenever possible.

4.2 Wellheads, Flowlines, Manifolds and Separation Systems

4.2.1 General

4.2.1.1 The piping system design shall provide access for periodic nondestructive testing for erosion.

4.2.1.2 Piping injection and sampling connections shall be of minimum length and protected from external mechanical damage. Each connection shall include a close-coupled block valve. A check valve shall be either close-coupled or integral to the block valve on injection line connections. The check valve shall be installed on the upstream injection side of the block valve.

4.2.1.3 Safety devices on manifold headers and flowlines shall be designed and installed in accordance with API RP 14C "Recommended Practice for Analysis, Design, Installation and Testing of Basic Surface Safety Systems on Offshore Production Platforms."

4.2.2 Wellhead Piping and Flowline Systems

4.2.2.1 The piping design and layout shall take into consideration independent wellhead movement due to wave action and wind forces.


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4.2.2.2 Piping shall not obstruct access necessary for well servicing.

4.2.2.3 Changes in direction shall not be permitted within 10 nominal pipe diameters downstream of wellhead chokes or throttling valves.

4.2.2.4 Changes in direction shall be made with cushion tees. A straight tee with a weld cap or blind flange installed on the end run may be substituted for a procured cushion tee. Wellhead flow shall enter the straight end run, and exit the branch side.

4.2.2.5 Production flowline check valves shall be located immediately upstream of the well manifold header tie-in block valve so as to protect the entire flowline from backflow.

4.2.2.6 Each injection flowline shall be provided with a check valve located at the wellhead so that the entire flowline is protected from backflow.

4.2.2.7 A branch block valve and quick disconnect shall be provided immediately upstream of each flow line check valve to permit de-pressuring and draining of the flowline into the relief header by using a temporary high pressure hose.

4.2.3 Manifold Systems

4.2.3.1 Short radius elbows in manifold assemblies shall be specifically prohibited and shall not be accepted by COMPANY under any circumstances.

4.2.3.2 Manifold headers shall be terminated with blind flanges on each end to provide a fluid cushion area and a means for rodding out.

4.2.3.3 Manifold inlet and outlet connections shall be provided with an isolation block valve. Header block valves shall include body bleed valves to facilitate testing for leaks.

4.2.3.4 Each riser and header on production manifolds shall be equipped with a drain valve for draining into the production manifold skid drain pan. Drains shall be piped to within 6" of the skid drain pan.

4.2.3.5 Manifold headers shall be designed, arranged and installed so that future expansion will not be obstructed by other piping or equipment.

4.2.4 Oil Separation Systems

4.2.4.1 Piping design layout shall avoid wet legs and vertical risers if possible.

4.2.4.2 The typical arrangement for a separation vessel piping system shall be in accordance with Figure 5.2 of API RP 14E "Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems." Required


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piping system components shall be provided as shown unless specified otherwise by the Technical Requirements.

4.3 Pressure Vessels

4.3.1 Process piping at vessel nozzles shall be provided with blanks or spectacle blinds to allow isolation of the vessel for inspection and maintenance.

4.3.2 A removable pipe spool shall be provided on the inlet (wellstream) to production and test separators.

4.3.3 Atmospheric vents from vessels shall be equipped with plugged or blanked shutoff valves.

4.3.4 For instrumentation connections, the first block valve off a vessel connection shall use a piping class ball valve as the root valve, unless specified otherwise by the Technical Requirements. Additional valves beyond the root valve shall be in accordance with the appropriate piping or instrumentation specification.

4.3.5 All vessel connections shall be flanged with a minimum size of 1-1/2" NPS, except that temperature and pressure gauges/transmitters may use 3/4" or 1" NPS screwed connections when specifically approved by COMPANY.

4.3.6 Liquid outlet headers shall be piped to permit gravity drainage from the vessel.

4.3.7 Lines carrying materials of high viscosity shall be designed with a continuous slope and shall drain into the vessel.

4.3.8 Vessel drains that discharge into an open drain system shall be piped from the block valve to a splash hub on the drain system to allow observation.

4.3.9 Vessel drains operated only during shutdown periods may be provided with plugs or blanks in lieu of permanently installed valves with COMPANY approval.

4.3.10 Vessel emergency shutdown valves shall be located within 30' of the vessel measured horizontally. The total pipe length from the vessel nozzle to the valve shall not exceed 50'. If, in addition to the normal control system, a manual actuation station is required, it shall be located at grade close to the shutdown valve in a location safe from fire exposure.

4.4 Fired Heaters

4.4.1 Fuel Oil

4.4.1.1 The fuel oil header at each fired heater shall be located above the burners and shall not be dead ended.


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4.4.1.2 Globe-type burner line valves shall be connected to the side or top of the header with lines draining to the burners.

4.4.1.3 Piping arrangements for air atomization shall provide safeguards to prevent fuel oil from entering the air system. Unless specified otherwise, a ball check valve shall be provided in each air connection. The check valve shall be installed at the burner with the valve in the up-flow position.

4.4.2 Fuel Gas

4.4.2.1 The piping arrangement for fuel gas systems on fired heaters shall be in accordance with Section 5.1 of this specification and the Technical Requirements.

4.4.2.2 Throttle valves for fuel gas service shall be of the globe or needle type. All other valves shall be fire safe ball valves.

4.4.2.3 The header that supplies the heater shall be provided with block and bleed valves. A spectacle blind shall be installed downstream from the block and bleed valves.

4.4.2.4 Bypass valves located at automatic control valves shall be ball or globe valves, of the vee-port type.

4.4.3 Miscellaneous

4.4.3.1 Burner control valves shall be located at a working level so that adjustments can be made while observing the flame.

4.4.3.2 Facility blowdown valves shall be located so that operation of the valves will not be affected by a fire at the heater.

4.4.3.3 Check valves shall be installed at the vessel end of the flow lines to prevent backflow when a heater or heat exchanger tube ruptures.

4.5 Heat Exchangers

4.5.1 Shell and Tube and Double Pipe Heat Exchangers

4.5.1.1 Process and water piping to heat exchangers shall be arranged to provide easy removal of shell covers, channel covers, channels and tube bundles.

4.5.1.2 Piping shall be arranged, or check valves shall be properly located to ensure that cooling water will remain in the exchanger should the cooling water supply be lost.

4.5.1.3 All vent valves shall be provided with plugs or blind flanges.


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4.5.2 Air-Cooled Heat Exchangers

4.5.2.1 Inlet and outlet headers shall not be located over or under the tube areas.

4.5.2.2 Piping connections to split-header bundles shall be designed to provide necessary flexibility to accommodate motion produced by differential temperature within the bundle.

4.5.2.3 Multiple bay heat exchangers with incoming two-phase flow regimes (other than the dispersed or bubble flow regions in a Baker flow map) shall be provided with a symmetrical inlet piping arrangement. The piping system shall consist of multiple cascading headers to equalize the flow to each bundle.

4.5.2.4 If the pressure drop from the header inlet to the most distant nozzle of the last heat exchanger in the row (Px) is less than 1/9 of the pressure drop through the heat exchanger (Py), single-phase flow headers may be arranged as a simple rake or comb-shaped manifold.

4.6 Pumps

4.6.1 Sufficient maintenance and access space shall be provided around pumps. The minimum maintenance width provided around pumps shall be 3'-0", except at the driver end where the width shall be a minimum of 5'-0". Piping shall not obstruct the driver end of horizontal pump skids under any circumstances.

4.6.2 Suction and discharge block valves shall be located as close as possible to the pump to permit removal of the pump without having to drain an excessive amount of piping or shut-in other equipment. Valve handwheels shall be arranged to project toward the major maintenance side of the pump installation but away from the pump.

4.6.3 Suction and discharge headers shall be extended to reach support beams and closed with a blind flange. No other method of support shall be acceptable.

4.6.4 Suction and discharge lines shall be independently anchored.

4.6.5 Piping shall be arranged to minimize flow turbulence, especially on the pump suction piping.

4.6.6 Elbows shall be installed to turn in the vertical plane.

4.6.7 Elbows in horizontal suction piping leading to double suction pumps shall be at least 5 pipe diameters upstream of the pump suction flange if a reducer is not utilized. A valve may be installed within the run, if the valve stem is located in the vertical position. If a reducer is located between the elbow and the pump flange, a straight run of at least 2 pipe diameters (based on the larger pipe) shall be provided. A reducer next to the pump flange shall be considered to be equivalent to three pipe diameters of the larger pipe.


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4.6.8 Horizontal reducers at pump suction connections shall be eccentric and installed with the flat side on top.

4.6.9 A concentric reducer shall be provided if the reduction occurs immediately before the elbow on the downcomer from overhead. If feasible and economical, a long radius reducing elbow shall be provided.

4.6.10 Piping shall be arranged to minimize the equivalent length of the suction piping, to eliminate liquid and vapor pockets, and to be slightly sloped toward the pump.

4.6.11 Suction piping shall be designed so that temporary start-up strainers can be easily installed or removed without springing the pipe.

4.6.12 Temporary start-up strainers shall be installed in the pump suction piping utilizing a removable spool between the pump and block valve as close to the pump as possible. Proper spacing shall be provided to allow for both the strainer and gaskets. The strainers shall have a free area a minimum of 300% of the pipe internal cross sectional area. The mesh size shall be approved by COMPANY and the pump manufacturer.

4.6.13 If specified in the Technical Requirements, permanent strainers shall be installed in the pump suction line. As a minimum, permanent strainers shall be installed in the suction line of pumps handling fluids that may contain solids, unless the pump is specifically designed to handle solids. Permanent strainers shall be tee type bathtub strainers for piping 8" NPS and larger.

4.6.14 CONTRACTOR shall submit the type, location, mesh size and material of all pump strainers to COMPANY for approval.

4.6.15 Drain lines for jacket and seal cooling water, packing flush and other pump fluids shall be piped to open drain hubs to allow observation. Fluids shall not be discharged onto the pump baseplate.

4.6.16 Shock absorbers or flexible connections shall be provided on reciprocating pumps if quick closing or remote control valves are installed in the discharge line. Shock absorbers or flexible connections shall be designed to prevent shock and minimize stress on the pump.

4.6.17 Suction and discharge pulsation dampeners shall also be considered on reciprocating pumps in order to reduce vibration and the impact of acceleration head in the suction piping.

4.6.18 For FRP piping systems, direction changes in close proximity to the pump discharge shall be avoided to the best extent possible.


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4.7 Compressors

4.7.1 General

4.7.1.1 Compressor piping shall be provided with blanks for isolating the compressor during hydrostatic testing and maintenance.

4.7.1.2 Suction and discharge headers shall be extended to reach support beams and closed with a blind flange. No other method of support shall be acceptable.

4.7.1.3 Piping on compressor skids shall be supported from the compressor structural skid.

4.7.1.4 Where compressors are connected to a common header, the piping system shall be designed to accommodate variations in piping temperatures that result from all combinations of operating and non-operating units.

4.7.1.5 Suction scrubbers shall be located as close to the compressor as possible.

4.7.1.6 Suction piping upstream of the suction scrubber and between the scrubber and the compressor shall be arranged to prevent trapping or liquid collection, and shall drain freely to the scrubber. Where it is impractical to prevent traps, additional knockout equipment shall be provided. The installation arrangement shall be approved by COMPANY.

4.7.1.7 Compressor suction block valves shall be located in horizontal runs of piping.

4.7.1.8 Temporary strainers shall be provided in all compressor suction lines 3" NPS and larger, and shall be installed in a removable spool piece as close to the compressor as possible. Proper spacing shall be provided to allow for both the strainer and gaskets. Temporary strainer design and mesh size shall be approved by COMPANY and the compressor manufacturer. The strainers shall have a free area a minimum of 300% of the pipe cross sectional area. Flow through conical type strainers shall be from outside to inside.

4.7.1.9 Where pulsation dampeners are provided, the suction scrubber shall be located upstream of the pulsation dampener.

4.7.2 Air Compressors

4.7.2.1 Suction piping for air compressors shall be equipped with a silencer and an air intake filter in accordance with the Technical Requirements.

4.7.2.2 Air compressor intake filter openings shall be located to minimize the entrance of dust, moisture, and corrosive gases.

4.7.2.3 Air compressor suction piping between the air filter and the compressor connection shall be fabricated of either galvanized or stainless steel piping, or an alternate corrosion resistant material if approved by COMPANY.


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4.7.3 Centrifugal Compressors

4.7.3.1 Check valves installed on the discharge of centrifugal compressors shall be quick response, non-slam type approved by COMPANY. Check valves shall be located as close to compressor discharge nozzles as feasible, but downstream of the antisurge connection.

4.7.3.2 Discharge antisurge lines shall also be equipped with a check valve. The check valve shall be located as close to the main discharge line as possible.

4.7.3.3 If manual suction, discharge, recycle and vent valves are required by the Technical Requirements, the valves shall be located together in one area for ease of startup and operation.

4.7.4 Positive Displacement Compressors

4.7.4.1 The arrangement of the bypass piping and location of the bypass valve shall prevent the collection of liquid when the valve is closed. If required by the Technical Requirements, bypass valves shall be automatically controlled.

4.7.4.2 The selection of discharge check valves shall be subject to approval by COMPANY. The check valve shall be of the dampened piston type.

4.7.4.3 Piping and pulsation bottles shall be supported independently and shall not be solely supported by the compressor cylinders. The support design shall allow hot adjustment.

4.7.4.4 The design of pressurizing lines installed around suction block valves shall approved by COMPANY.

4.7.4.5 Unless specified otherwise, the suction and discharge block valves and vent valves shall be manually operated and shall be located together in one area for ease of startup and operation.

4.7.4.6 Drain piping shall be provided from each compartment on cylinder manifolds and pulsation dampeners.

4.7.4.7 For compressor systems 1000 horsepower and above, an analog study of the complete system shall be provided. The analog study shall include all piping and equipment (scrubbers, coolers, pulsation dampeners, compressors, etc.) from the first stage suction scrubber to the last discharge cooler and scrubber on the final stage.


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4.8 Erosion Monitoring

4.8.1 General

4.8.1.1 Erosion monitoring systems shall be in accordance with NACE RP-07 "Preparation and Installation of Corrosion Coupons and Interpretation of Test Data in Oil Production Practice."

4.8.1.2 Erosion monitoring systems shall be arranged in a compact manner that allows for ease of installation and removal of erosion coupons and probes without depressurizing the piping system. The arrangement shall ensure maximum safety to personnel performing the work, and minimize the potential for the escape of process fluids.

4.8.1.3 The system shall not interfere with the maintenance or operational access of other piping, valves, instruments or equipment.

4.8.1.4 Erosion monitoring systems shall be designed for insertion of a test probe or coupon directly into the flow stream.

4.8.1.5 Erosion coupons and probes shall be placed in piping systems where the presence of sand or two phase flow might cause erosion of the piping. Piping that commonly requires erosion monitoring equipment includes production flow lines, manifolds, and headers upstream of the initial surge vessel, flow splitter, production separator and test separator.

4.8.1.6 Unless specified otherwise, erosion monitoring equipment shall be of the probe type if sand is present in the flow stream. Erosion monitoring devices for other service conditions shall be of the coupon type.

4.8.2 Access Fittings

4.8.2.1 Access fittings and piping shall be in accordance with ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping" and API RP 14E "Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems."

4.8.2.2 Access fittings shall be flanged type and shall provide adequate support for the coupon or probe holder, an accurate indication of the position of the coupon or probe in the pipe, and a protective cover for the probe holder.

4.8.2.3 Access fittings shall be of the same material as the piping to which they are attached. Access fittings shall be located at the top of the pipe. A minimum clearance of 5'-0" shall be provided directly above the fitting to allow access for the removal tool.

4.8.2.4 The plug body shall provide support for the coupon or probe and shall seal the pressure of the piping system.


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4.8.2.5 Plug bodies and assemblies shall be 18-8 stainless steel with tetrafluorethylene polymer (TFE) packing.

4.8.3 Probes

4.8.3.1 Probes shall be installed primarily in service where sand is present in the flow stream.

4.8.3.2 Probes shall be installed in the top of the pipe and shall extend into the pipe a distance equal to approximately 60% of the inside diameter of the pipe.

4.8.3.3 An instrument block valve shall be provided to isolate the pressure switch from the erosion monitoring system. The valve shall be constructed of 18-8 stainless steel as a minimum, and shall be suitable for the service.

4.8.4 Coupons

4.8.4.1 Unless specified otherwise, coupons shall be of the single pair, strip type constructed of the same material as the piping system to be monitored.

4.8.4.2 Coupons shall be located to monitor the area of highest anticipated erosion with the edge facing the fluid flow.

4.8.4.3 Coupons shall be electrically isolated from the coupon holder by insulating material suitable for the service.

4.8.5 Retrieval/Installation Tools

4.8.5.1 Retrieval/installation tools shall be designed to remove and install the monitoring devices through access fittings with the line fully pressurized.

4.8.5.2 Valves used with the tools shall be of the fire safe type in accordance with the requirements of API SPEC 6A "Specification for Wellhead Equipment" and API SPEC 6D "Specification for Pipeline Valves, End Closures, Connectors, and Swivels."

4.8.5.3 Tools shall be designed to allow safe bleed-off of any residual pressure remaining in the tool after removal from the access fitting.

4.9 Chemical Injection

4.9.1 Flanges in chemical injection piping shall not be located over walkways, stairways, access areas, maintenance areas, etc., unless approved by COMPANY.

4.9.2 Whenever possible, chemical injection lines shall be run under walkways.


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4.9.3 Instrument tubing and compression fittings may be used for injection pump suction and discharge piping subject to the following conditions:

a. No joints shall be allowed over walkways, stairways, access and maintenance areas, etc.

b. Tubing shall be fully supported within tubing tray.

c. Tubing shall be labeled with service (chemical).

4.9.4 Deck penetrations shall be prohibited within the contained area of the chemical storage tanks.

4.10 Sample Connections

4.10.1 Sample connections shall be installed in the side of piping rather than on the top or bottom.

4.10.2 If practical, sample connections shall be located close to oily water drains.

4.10.3 Sample lines shall be as short as practical.

5.0 UTILITY SYSTEMS

5.1 Fuel and Utility Gas

5.1.1 Piping systems for fuel, utility, blanket and purge gas service shall be in accordance with ANSI B31.2 "Fuel Gas Piping," ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping," NFPA 37 "Standard for the Installation and Use of Stationary Combustion Engines and Gas Turbines," NFPA 54 "National Fuel Gas Code," and the Technical Requirements.

5.1.2 Piping shall be routed to avoid liquid traps if at all possible. If liquid traps cannot be avoided, a condensate leg with a 3/4" NPS block valve (with a plug or blind flange) shall be installed at the low point.

5.1.3 Valved vents shall be provided at high points to release trapped air from the piping high points. On purge gas systems, all vents shall either be accessible from platforms or shall be arranged in one area next to a structural support to allow sniffing for oxygen.

5.1.4 Fuel gas distribution headers shall be arranged for uniform distribution of gas. Headers shall be located above the burners and shall be provided with drains installed at all low points, complete with plugs or blind flanges.

5.1.5 Burner supply lines shall be connected to the top of the header to minimize liquid carryover. A drain valve shall be provided in each supply line close to the burner, complete with plugs or blind flanges.


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5.1.6 Burner fuel gas piping shall have a union or flange disconnect at each burner and shall be arranged to permit individual burner removal without interrupting operation of the rest of the system.

5.1.7 Blanket gas regulators and ball valves shall be located as close to the equipment as possible, but shall be accessible from grade or a platform.

5.1.8 Purge gas block valves and blow down valves shall be located as close as possible to the loading valve or system terminating point opposite the flare header.

5.2 Instrument Air

5.2.1 Piping Sizes

5.2.1.1 The minimum size for instrument air headers shall be 2" NPS, and for subheaders 1-1/2" NPS.

5.2.1.2 The minimum size for branch lines shall be 1" NPS.

5.2.1.3 The minimum size for supply lines to instruments shall be 1/2" NPS.

5.2.1.4 Instrument supply from the supply line shutoff valve to the instrument shall normally be 3/8" tubing. Tubing for large pneumatic actuators shall be 1/2" minimum.

5.2.1.5 All headers, subheaders, branches and supply lines shall be properly sized based on instrument air usage. As a minimum, instrument air piping shall meet the following minimum size requirements:

Nominal Pipe Size:(inches)

Maximum Number of InstrumentConnections:

1/2 43/4 101 25

1-1/2 802 150

5.2.2 Design and Layout

5.2.2.1 Instrument air headers in process pipeways shall be of the loop type if possible.

5.2.2.2 Instrument piping shall be routed overhead and supported to provide a neat, plumb, level, vibration free installation.

5.2.2.3 Headers and subheaders shall be arranged so that groups of instruments can be isolated without effecting the air supply to the rest of the system.


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5.2.2.4 Headers and subheaders shall be arranged to allow free flow through a full size opening to facilitate final cleaning of the air system.

5.2.2.5 Subheader or branch connection takeoffs shall be provided along the entire length of a header. Takeoffs shall be spaced at intervals of no more than 25'.

5.2.2.6 A minimum of 20% spare subheader and branch connections shall be provided on all headers, and shall be evenly distributed along the header. All spare connections shall be provided complete with block valves and plugs or blind flanges unless specified otherwise.

5.2.2.7 Pressure gauges shall be located at the beginning and end of all headers and at the end of all subheaders, and shall be readable from the deck or access platforms.

5.2.2.8 The piping arrangement shall minimize low points and liquid traps.

5.2.3 Instrument Supply Lines

5.2.3.1 Instrument air supply lines shall be taken from the top of the header, subheader or branch.

5.2.3.2 Each air line takeoff shall be provided with a block valve. If an air line serves more than one instrument, a separate block valve shall be provided on each instrument supply line.

5.2.3.3 Instrument supply lines shall terminate with a shutoff valve located not more than 3'-0" from the instrument.

5.2.3.4 Instrument supply line piping shall be installed with sufficient flexibility to accommodate normal maintenance and equipment movement.

5.3 Utility Air

5.3.1 General

5.3.1.1 The utility air main header shall start at the air receiver nozzle and terminate with blind flanges on each platform deck.

5.3.1.2 The minimum size of for utility air headers shall be 2" NPS, and for hose station branches 1" NPS.

5.3.1.3 Branch connections shall be located on the top of the main header, and block valves shall be supplied for each branch connection.

5.3.1.4 Pressure gauges shall be located at the beginning and end of all headers, and shall be readable from the deck or access platforms.


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5.3.1.5 The piping arrangement shall minimize low points and liquid traps.

5.3.2 Hose Stations

5.3.2.1 Hose stations shall be provided in sufficient quantities, and properly located to provide full deck area coverage utilizing 50' long hoses.

5.3.2.2 Hose stations shall be provided with a 1" NPS ball valve and a 1" NPS quick disconnect fitting.

5.3.2.3 Hose connections shall be mounted on fixed platform handrails or on structural members approximately 3'-6" above the deck.

5.4 Cooling Water

5.4.1 Heat Exchangers

5.4.1.1 Piping connections to heat exchangers shall be designed to facilitate equipment removal by means of breakout spools, preferably with a change in direction to facilitate removal.

5.4.1.2 Where inlet and outlet temperature/pressure indicators are installed in the piping, they shall be located within 18" of the exchanger connection.

5.4.1.3 For cooling water piping systems associated with process liquid or gas heat exchangers, the piping shall not be located over the heat exchanger tube bundle pull area.

5.4.2 Internal Combustion Engines

5.4.2.1 Cooling water valves shall be installed with the valve stem oriented in the down position to prevent flow blockage in the event of valve stem failure.

5.4.2.2 If practical, piping shall be arranged, or check valves shall be properly located to ensure that cooling water will remain in the exchanger should cooling water supply be lost.

5.4.2.3 Each inlet and outlet line serving components that require periodic removal for servicing and maintenance shall be provided with Dresser style connectors with resilient, replaceable seals.

5.4.2.4 Cooling water headers and piping supported from the engine shall be of welded or flanged construction regardless of the pipe class specified.

5.5 Lube and Seal Oil Systems

5.5.1 Interconnecting piping on lube and seal oil systems shall be in accordance API Standard 614 "Lubrication, Shaft-Sealing, and Control Oil Systems for Special-


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Purpose Applications" and the Technical Requirements, unless specified otherwise by COMPANY.

5.5.2 As a minimum, lube oil piping systems shall utilize 316L stainless steel construction on the main filters and all piping and valving downstream of the filter. Screwed fittings and components in lube oil piping systems shall be held to a minimum. Where accepted, screwed components shall be seal welded, except where removal is necessary such as at instruments and instrument root valves.

5.5.3 Seal oil piping systems shall be 316L stainless steel construction. Screwed fittings shall not be acceptable in seal oil piping systems.

5.5.4 Both lube oil and seal oil piping systems shall have provisions for flushing the entire piping system prior to start-up.

5.5.5 Cooler connections and skid cooling water supply and return connections shall be flanged.

5.5.6 Vent lines from main filters shall be piped back to the oil reservoir.

5.5.7 Drain lines with plugs or blind flanges shall be provided at all locations necessary to completely drain the piping system.

5.5.8 Oil drain lines shall be sloped at least 1/4" per foot of pipe run.

6.0 PRESSURE RELIEVING SYSTEMS

6.1 General

6.1.1 Pressure relieving systems shall be designed so that the relief device is mounted as close as possible to the equipment or pressure system being protected. Pressure relieving systems shall be in accordance with API RP 520 "Recommended Practice for the Design and Installation of Pressure-Relieving Systems in Refineries," Part II and API RP 521 "Guide for Pressure Relief and Depressuring Systems."

6.1.2 Pressure relieving systems for corrosive, toxic, or sour gases shall not discharge to the atmosphere.

6.1.3 Pressure relief piping shall be designed to accommodate thermal contraction resulting from auto-refrigeration of flashing liquids and expanding gases, and to accommodate thermal expansion caused by sudden heating as a result of high temperature release.

6.1.4 Discharge headers for pressure relieving systems shall be routed as straight as possible, minimizing the number of fittings and elevation changes. Headers and


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piping shall include a minimum slope of 1/4" per 10'-0" of pipe run in the direction of relief flow.

6.1.5 Liquid pockets and traps shall be avoided if possible. If unavoidable, they shall be provided with a 3/4" NPS valved drain routed to the closed drain system.

6.1.6 Relief systems with two or more relief valves shall be designed and arranged so that one valve does not discharge directly into the other.

6.1.7 Pressure relieving systems shall be supported with gussets, stiffeners, or stationary supports designed to absorb reaction forces from the worse case relief conditions.

6.2 Open Relief and Vent Systems

6.2.1 Vent stacks for open relief systems shall be designed in accordance with API RP 520 "Recommended Practice for the Design and Installation of Pressure-Relieving Systems in Refineries," and API RP 521 "Guide for Pressure Relief and Depressuring Systems."

6.2.2 Vent stacks shall terminate in a vertical run, and shall be located a minimum of 10'-0" above all platform areas within a 25' radius.

6.2.3 Relief systems for flammable gases discharging directly to atmosphere shall be equipped with a flame arrestor. Flame arrestors shall be located no further than 4'-0" from the end of the vent pipe unless approved otherwise by COMPANY.

6.2.4 A weep hole shall be provided in the horizontal pipe run just downstream of the relief valve. Minimum hole size shall be 3/8" diameter.

6.3 Closed Relief Systems

6.3.1 Closed relief systems that discharge into a common header shall be designed with the pressure relieving device located above the header.

6.3.2 If the pressure relieving device cannot be located above the header, a 3/4" NPS valved drain shall be installed in the discharge piping at the lowest point and routed to the closed drain system.

6.3.3 Relief lines shall enter headers on the top in the vertical plane, at a 45o angle with flow directed parallel to the flow in the header. If conditions do not allow entry into the top of the header, alternate entry may be into the side, but never into the bottom.

6.4 Conventional and Pilot Operated Relief Valves

6.4.1 Conventional and pilot operated relief valves shall be connected to vessels in the vapor space above any contained liquid. If the relief valve inlet is attached to


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piping, the piping shall be connected to the vessel in the vapor space above any contained liquid.

6.4.2 Discharge lines from pressure relieving safety devices shall be designed to facilitate drainage, or shall be fitted with drains that discharge into a safe location approved by COMPANY.

6.4.3 Relief valves shall be installed in the upright (vertical) position with the spindle vertical, unless space or piping configuration preclude such an installation. The valve may be installed in other positions with COMPANY approval, provided that:


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• The valve design is satisfactory for such position.

• The process fluid is such that material will not accumulate at the inlet of the valve.

• Proper drainage of the discharge side of the valve body and the discharge piping is provided.

6.4.4 Relief valves shall not be installed in the horizontal position without prior written approval from COMPANY.

6.5 Thermal Reliefs

Pressure relieving systems for equipment or pressure systems that handle or process flammable liquids or gases shall be designed for thermal relief in accordance with API RP 520 "Recommended Practice for the Design and Installation of Pressure-Relieving Systems in Refineries," and API RP 521 "Guide for Pressure Relief and Depressuring Systems."

6.6 Rupture Disks

6.6.1 Rupture disks for pressure relief systems shall be in accordance with the ASME "Boiler and Pressure Vessel Code," Section VIII "Pressure Vessels."

6.6.2 When rupture disks are located upstream of a relief valve, the pressure relieving system shall be designed so that if the disk ruptures, the fragments do not interfere with the relief valve seating.

6.7 Flare Systems

6.7.1 Flare systems for pressure relieving systems shall in accordance with API RP 521 "Guide for Pressure Relief and Depressuring Systems" and the Technical Requirements.

6.7.2 Flare systems shall be of the boom or vertical type, and located on the platform or at a remote location in accordance with the Technical Requirements.

7.0 FIRE PROTECTION SYSTEMS

7.1 Firewater Systems

7.1.1 Firewater systems shall be in accordance with NFPA 13 "Standard for the Installation of Sprinkler Systems" and the Technical Requirements.

7.1.2 Risers or vertical pipe 3" NPS and larger shall have a flanged joint or a mechanical coupling at each deck level.

7.1.3 Changes in pipe size shall be made with a one piece reducing fitting. Reducing bushings, couplings and unions shall not be acceptable.


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7.1.4 A maximum of eight sprinklers may be installed on any single branch line.

7.1.5 All sprinkler pipe and fittings shall be designed and installed so that the firewater system can be drained completely, including both wet and dry type systems. Branch lines shall include a minimum slope of 1/2" for each 10'-0" of pipe run. Cross and feed mains shall include a minimum slope of 1/4" for each 10'-0" of pipe run.

7.1.6 Firewater systems shall minimize low point traps to make the system as "self draining" as reasonably possible. Where unavoidable, low point traps shall be provided with drain valves. Drain valves shall also be provided at the ends or remote points in the system. The minimum size for drain valves shall be 1" NPS.

7.2 Foam Systems

7.2.1 General

7.2.1.1 Foam systems shall be in accordance with NFPA 11 "Low Expansion Foam and Combined Agent Systems" and the Technical Requirements.

7.2.1.2 Strainers shall be provided if solids large enough to obstruct openings in foam equipment might be present.

7.2.1.3 In fixed systems for exterior tanks, one flanged or union joint shall be provided in each riser to permit hydrostatic testing of the piping systems up to this joint.

7.2.1.4 The laterals to each foam chamber on fixed roof tanks shall be separately valved outside the fire area.

7.2.2 High Back-Pressure Foam Makers

7.2.2.1 High back-pressure foam makers shall be positioned on the tank so that an explosion within the tank which blows off the roof or damages the uppermost roof plates would not result in the interruption or reduction of quality of the foam discharge.

7.2.2.2 The foam injection system shall be capable of being injected directly into one or more product supply lines already connected to the tank.

7.2.2.3 The water line to each high back-pressure foam maker inlet shall be valved separately.

7.2.3 Flushing and Draining Provisions

7.2.3.1 Systems with foam concentrate piping and solution piping that are normally empty shall be designed so that the piping can be flushed with clean water after the system has been in service.


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7.2.3.2 Foam distribution piping shall be designed so that the system can be drained. The piping shall be sloped toward the drain a minimum of 1/2" for each 10'-0" of pipe run.

7.3 Carbon Dioxide (CO2) Systems

7.3.1 Carbon Dioxide (CO2) Systems shall be in accordance with NFPA 12 "CO2

Extinguishing Systems" and the Technical Requirements.

7.3.2 Flow in piping shall only be split in the horizontal plane.

7.3.3 A dirt trap consisting of a capped nipple at least 2" long shall be provided at the end of each pipe run. Dirt traps shall be installed as close as possible to the last nozzle in any one pipe leg.

7.3.4 Pressure relief devices shall be installed in sections of closed piping isolated by valves, unless the valves are designed to prevent entrapment of liquid.

7.3.5 If pressure operated container valves are installed in a system, a means for venting off any pressure that leaks from the containers shall be provided. The design for venting shall not permit loss of extinguishing agent when the system operates.

8.0 VENTS, DRAINS, FLUSHING AND CLEANING SYSTEMS

8.1 General

8.1.1 Separate gravity drain headers shall be provided for each deck level.

8.1.2 Headers shall be located below deck level, shall include sufficient blind flanges to enable complete cleanout, and shall have a minimum slope of 1/4" per foot of pipe run.

8.2 Vent Connections

8.2.1 Vent connections shall be provided at all piping high points. Vent connections shall be adequately sized to vent piping within a reasonable period of time, but shall be 3/4" NPS as a minimum.

CONTRACTOR shall note that P&ID's typically specify only those vents required for process purposes, and are by no means complete relative to high point vents. The absence of vent connections on the P&ID's shall not constitute a waiver of the requirement to provide valved vents at all piping high points.

8.2.2 Vent connections shall be provided with permanent block valves, including plugs or blinds, unless specified otherwise by the Technical Requirements.


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8.2.3 Vent connections in services rated at ANSI Class 600 or less shall be equipped with a single block valve.

8.2.4 Vent connections in services rated at ANSI Class 900 or higher shall be equipped with double block and bleed valves.

8.2.5 Vent connections in liquid hydrocarbon services with a vapor pressure over 65 psia at 100°F shall be provided with double block and bleed valves. The first block valve shall be a gate valve, and the second block valve shall be a plug type globe valve, complete with a plug or blind flange. The block valves shall be spaced approximately 2'-0" apart, and a spectacle blind provided between them. Additionally, a 3/4" NPS bleed valve (with plug or blind flange) shall be installed on the upstream side of the spectacle blind.

The gate valve shall be guaranteed not to be impaired by rapid temperature reduction when the valve is opening or throttling, as would be experienced in liquefied petroleum gas (LPG) service for example.

8.3 Drainage Systems

8.3.1 General

8.3.1.1 Offshore platform drainage and waste disposal systems shall be designed in accordance with API RP 14E "Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems," the latest edition of MMS Outer Continental Shelf (OCS) Order No. 5 (i.e. CFR 30, Part 250), and all national, state and local codes and regulations. The design of all offshore platform drainage and waste disposal systems shall be subject to approval by COMPANY.

8.3.1.2 Segregation of wastes, oil recovery sludge disposal, biological and chemical treating and other disposal problems shall be considered in the design of the drainage systems. A separate collection system shall be provided to collect, store and dispose of refined oils drained from equipment.

8.3.1.3 Open drain systems and closed drain systems shall be completely independent of one another.

8.3.1.4 Sizing of sanitary drains shall be based on Uniform Plumbing Code fixture unit values. The minimum size for any single branch into a header shall be 4" NPS. The minimum size for any header containing the flow of two or more branch lines shall be 6" NPS. All sanitary drain piping shall slope a minimum of 1/4" per foot of pipe run.

8.3.2 Open Drain System

8.3.2.1 CONTRACTOR shall be responsible for overall design of open drain systems to ensure that water will drain properly and not stand or pond at any location.


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Responsibility includes the design, sizing, layout and quantity of deck drains and troughs; sizing and routing of drain lines, branches and mains; and locating cleanouts and flushing tees.

8.3.2.2 The minimum size for any single drain line shall be 3" NPS, except that drain lines less than 8'-0" in length may be reduced to 2" NPS. The minimum size for any single branch line shall be 4" NPS. The minimum size for any main containing the flow of two or more branch lines shall be 6" NPS.

8.3.2.3 Hydrocarbon open drain systems shall not be installed within enclosed areas (such as a building) unless the hydrocarbon open drain systems are piped to a safe area before making the connection to a gravity drain system.

8.3.2.4 If necessary, pipe, hubs, and funnels shall be provided to drain oil and chemicals to suitable drain piping.

8.3.2.5 Removable bar grating shall be provided on the top of open type drains to provide access for cleaning. Individual collection drains shall be designed to prevent small debris and trash from entering the platform drain piping.

8.3.2.6 Changes in direction on open drain headers shall be made with a 45o lateral ("wye" type tee) and a 45o ell, complete with a flushing tee. Drain and branch lines shall enter open drain headers at a 45o angle from the top or side utilizing a 45o lateral, and a 45o ell if needed. Laterals shall be constructed flush with the inside of the main pipe, i.e. no internal projection.

The ends of all headers shall be terminated with blind flanges to facilitate cleaning and unplugging.

8.3.2.7 Liquid seals shall be provided in accordance with the Technical Requirements, and shall be provided with either a drain valve or a plugged drain connection. As a minimum, liquid seals shall be provided on each deck drain main tying into the main drain downcomer, and on branch piping from skids located inside buildings. Containment curbs shall be provided under all liquid seals.

8.3.2.8 Spillover (overflow) pipes from vessels and tanks shall discharge into an open drain splash hub to allow observation that the vessel or tank is being overfilled.

8.3.2.9 Where specified, CONTRACTOR shall provide a drilling drain/wash down system which shall be completely independent of other open or closed drain systems. The system shall be provided with cleanouts, flushing tees and/or tie-in points for jetting of the piping. Access shall be provided to all cleanouts.

8.3.3 Low Point Drains

8.3.3.1 Drain connections shall be provided at all piping low points. Drain connections shall be adequately sized to drain the piping within a reasonable period of time


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under gravity conditions, i.e. not pressurized. As a minimum, drains shall be 3/4" NPS on lines 10" NPS and smaller, and 1" NPS on lines 12" NPS and above.

CONTRACTOR shall note that P&ID's typically specify only those drains required for process purposes, and are by no means complete relative to low point drains. The absence of drain connections on the P&ID's shall not constitute a waiver of the requirement to provide valved drains at all piping low points.

8.3.3.2 Drain connections shall be provided with permanent block valves, including plugs or blinds, unless specified otherwise by the Technical Requirements.

8.3.3.3 Drain connections in services rated at ANSI Class 600 or less shall be equipped with a single block valve.

8.3.3.4 Drain connections in services rated at ANSI Class 900 or higher, as well as services with lower ratings but operating in hazardous areas shall be equipped with double block and bleed valves.

8.3.3.5 In liquid services where the liquid is pentane or heavier, with check valves located in vertical lines, a valved drain shall be installed above the seat of check valves, i.e. downstream of the valve to allow drainage.

8.3.3.6 Drain valves, if practicable, shall be located so that discharge can be observed.

8.3.3.7 Drain valves that are commonly operated shall be piped from the block valve to a splash hub for observation.

8.3.3.8 If approved by COMPANY, small drain lines may be disconnected from valves and the valves plugged when the drain lines are not in service.

8.4 Flushing Systems

8.4.1 If specified by the Technical Requirements, permanent backwash and chemical flushing facilities shall be provided for heat exchangers.

8.4.2 Tanks involved in flushing operations shall be designed for thorough cleaning after flushing operations.

8.4.3 Flushing systems shall utilize full pipe openings (not vent and drain connections) that permit a fluid flowrate sufficient to ensure that the line is cleaned completely.

8.5 Cleaning Systems

8.5.1 If specified by the Technical Requirements, a pressurized water cleaning system shall be provided for flushing gravity open drain systems. Cleaning tees shall be provided at all changes of direction instead of elbows.


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8.5.2 Each cleaning tee shall consist of a straight tee, a blind flange with a 1.09" bore, a 3/4" NPS gate valve, a 3/4" NPS Schedule 40 plain end pipe, and a 3/4" NPS butt welded 90 degree elbow.

8.5.3 Cleaning tees shall be arranged so that the 3/4" NPS flushing piping projects through the blind flange and is open ended 1" above the branch or main invert elevation. The 3/4" NPS gate valve shall be installed on the pipe projection outside the blind flange.

9.0 INSTRUMENTATION

9.1 General

9.1.1 As a minimum, instrument connections and the first block valve of instrument pressure piping shall conform to the same design and material specifications as the line or the equipment to which the instrument or valve connects.

9.1.2 All instrument root valve connections shall be 1/2" NPS screwed connections, unless specified otherwise by the Technical Requirements.

9.1.3 Provisions for rodding out instrument connections to prevent plugging shall be considered on an individual basis. The design details for rodding out individual connections shall be subject to approval by COMPANY.

9.1.4 Locally mounted instruments shall be mounted in positions that are readily accessible from grade or from an operating platform. Mounting positions generally shall be between 3'-0" and 5'-6" above the deck or access platform, and easily within reach of operating personnel.

9.2 Flow Instruments

9.2.1 General

9.2.1.1 Flow instruments shall be installed in accordance with the Technical Requirements.

9.2.1.2 Positive displacement meters shall be installed according to the following API standards.

STD 1101 "Manual of Petroleum Measurement Standards," Chapter 5, Section 2 "Measurement of Petroleum Liquid Hydrocarbons by Positive Displacement Meter"

STD 2531 "Manual of Petroleum Measurement Standards," Chapter 4, Section 2 "Mechanical Displacement Meter Provers"

STD 2534 "Manual of Petroleum Measurement Standards," Chapter


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5, Section 3 "Turbine Meters"

9.2.1.3 A basket or bathtub type strainer shall be provided upstream of all positive displacement meters, installed a minimum of ten pipe diameters upstream of the meter.

9.2.1.4 Strainers shall be installed to permit cleaning without the necessity of draining long sections of pipe.

9.2.2 Meter Runs

9.2.2.1 Meter runs shall be installed horizontally, with as the maximum length straight run pipe provided upstream of the orifice as practical. Piping layouts shall be designed such that straightening vanes are not required for meter runs.

9.2.2.2 If possible, meter run piping shall be installed so that air in the line will be purged automatically and so that any condensate will drain into the meter run.

9.2.2.3 Wellhead wet gas meter runs shall be installed vertically with flow directed downward.

9.2.3 Orifice Fittings and Plates

9.2.3.1 Orifice fittings on horizontal meter runs in gas measurement service shall be installed so that the orifice plate can be removed horizontally. The lower side of the fittings on the upstream pressure connections shall be equipped with drain valves.

9.2.3.2 Orifice fittings on horizontal meter runs in liquid measurement service shall be installed so that the orifice plate can be removed from the top.

9.2.3.3 Mating flanges of orifice plate holders shall be aligned so that jackscrews will be diametrically opposed.

9.2.3.4 Orifice fittings shall be provided with 1/2" NPS full opening "male x female" valves. If the "male x female" valves interfere with the operation of the orifice fitting, then "female x female" valves with 1/2" NPS nipples (schedule 160) may be provided.

9.2.3.5 Short or long pattern valves shall be provided as required by the particular installation.

9.2.4 Rotameters

9.2.4.1 Rotameters shall be mounted in locations that are as free of vibration as possible.


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9.2.4.2 Rotameters shall be mounted vertically, with flow directed upward, allowing sufficient clearance to permit vertical connection of the inlet piping to the bottom of the meter.

9.2.4.3 Piping for rotameters shall be provided with drain and vent valves and designed to allow sufficient clearance for removal of the floats without disturbing the rotameter.

9.2.4.4 If necessary to prevent complete unit shutdown, rotameter piping shall be provided with block valves and a bypass valve. The valve installation shall have sufficient clearance for rotameter removal.

9.3 Level Instruments

9.3.1 Level instrument installations shall be in accordance with the Technical Requirements.

9.3.2 Each level instrument shall have individual, valved connections so that isolation of one instrument will not affect other instruments.

9.3.3 On pressure vessels and tanks, level instruments shall be direct connected to vessel or tank nozzles. Use of bridles or standpipes shall require approval of COMPANY. Level instruments shall not be connected to process lines under any circumstances.

9.3.4 Vessel nozzles for external level instruments shall be horizontal and the connecting piping shall not be pocketed. Exceptions may be granted for small diameter horizontal vessels, but COMPANY approval shall be required.

9.3.5 Level instruments and gauge glasses may share a common standpipe as described in API RP 550 "Manual on Installation of Refinery Instruments and Control Systems," Part 1 - Process Instrumentation and Control, Section 2 - Level.

9.3.6 Level measurement standpipes shall conform to vessel design conditions, but shall be 2" NPS, schedule 80 pipe as a minimum.

9.3.7 Standpipes shall be provided with process block valves at the vessel nozzles.

9.3.8 Standpipes shall be equipped with vent and drain valves.

9.3.9 Drain valves shall be installed on all low point connections.

9.4 Pressure Instruments

Pressure instrument installations shall be in accordance with the Technical Requirements.


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9.5 Temperature Instruments

9.5.1 Temperature instrument installations shall be in accordance with the Technical Requirements.

9.5.2 Thermowells in carbon steel piping with an ANSI Class 600 rating or lower shall utilize a 1" NPS screwed connection, unless specified otherwise. Thermowells shall not be backwelded to the piping connection.

9.5.3 Thermowell connections shall utilize a 1-1/2" NPS flanged connection for the following services:

• Piping in ANSI Class 900 and higher ratings• Alloy piping services• Lined piping services• Hydrogen sulfide or other toxic gas services.

9.5.4 If the Material Class Data Sheet requires Schedule 160 or double extra strong pipe, the thermowell shall be installed in a 1-1/2" NPS long weld neck flanged nozzle.

10.0 CONTROL VALVES

10.1 General

10.1.1 Control valve stations shall have a compact arrangement with sufficient clearance for removal and operation of all control, block and bypass valves, instruments and associated controls without requiring disassembly of any other components. Station clearance shall be in accordance with ISA RP 4.2 "Standard Control Valve Manifold Designs."

10.1.2 Break flanges shall be installed upstream and downstream of the control valve for ease of removal and maintenance.

10.1.3 Where a control valve is less than line size, an eccentric reducer shall be installed with the flat side down to allow complete drainage. The reducer shall be located as close as possible to the valve, allowing only enough space to service equipment.

10.1.4 Control valve stations shall be supported with base ells and/or other suitable types of supports.

10.1.5 A drain valve shall be located between the control valve and each block valve.

10.1.6 Sufficient flexibility shall be built into the control valve station to permit replacement of the valve without damage to gaskets. For this reason, the preferred layout shall be to provide a removable pipe spool between the control valve and a block valve that includes an elbow.


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10.1.7 Control valve actuators shall be oriented in the vertical position. Orientation of control valves with the actuator down shall require approval by COMPANY and the valve position shall be noted on the procurement specification.

10.2 Piping Sizes and Pressure Drop

10.2.1 Piping shall be self supporting to allow control valve removal and maintenance.

10.2.2 Control valves in vapor recycle or flashing liquid service shall be located as near as practical to the line termination. The downstream piping shall be at least one nominal pipe size larger than the upstream line, and as short as possible with a minimum of bends and elbows to minimize the downstream pressure drop.

10.2.3 In some cases, pressure and/or flow conditions may vary sufficiently to require a larger (or smaller) control valve in the future. If a different control valve is required, the piping shall be designed for the larger size. Provisions shall be made to facilitate the change without major piping modifications, such as removable spools with flanged connections.

10.3 Station Arrangements

10.3.1 If possible, control valve stations shall be located at deck level. If instrument and control valve stations cannot be located at deck level, an easily accessible service platform shall be provided around the station. Control valve stations shall not be located in an overhead pipe rack under any circumstances.

10.3.2 The controlled-variable indicator shall be readable from the control valve station, especially where a manual control bypass is provided.

10.3.3 Bypass valves shall be located where the operator can reach the handwheel either from the deck or an easily accessible elevated platform.

10.3.4 Chain operators shall not be permitted on control valve block or bypass valves.

10.3.5 Where a control valve requires bottom access the following requirements shall apply:

a. For control valves 3" NPS or smaller, the centerline of the valve shall be located a minimum of 18" above the deck or the operating platform.

b. For control valves 4" NPS or larger, the centerline of the valve shall be located a minimum of 2'-0" above the deck or operating platform.

11.0 SPECIALTY ITEMS

11.1 General

11.1.1 Specialty items shall be of standard sizes, as specified in the applicable piping class specification.


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11.1.2 Specialty item materials shall be consistent with the applicable Material Class Data Sheet as specified in the Technical Requirements.

11.2 Blanks

11.2.1 Provisions for installing blanks in piping shall consist of a pair of flanges, one of which may be on a flanged valve or a piece of equipment.

11.2.2 Removable pipe spools or spacers shall be installed at raised face or ring type joint flanges too rigid to separate with jackscrews.

11.2.3 For blanks weighing more than 75 pounds, flange faces shall be oriented in the vertical position.

11.2.4 Permanent handling equipment shall be provided for blanks weighing more than 175 pounds, unless mobile lifting equipment can be easily utilized.

11.3 Strainers

11.3.1 All Y-type strainers shall be installed with the basket directed downward. Adequate space shall be provided to remove the basket from the bottom.

11.3.2 Simplex/duplex basket strainers shall be installed in the upright position to allow the basket to be lifted out from the top.

11.3.3 Bathtub type strainers shall be installed in the upright position in horizontal lines to allow top entry, or with flow in the downward direction in vertical lines.

11.3.4 Strainer bonnets shall be provided with a stainless steel "male x female" threaded ball valve and plug in accordance with the material classification.

11.3.5 Strainers installed upstream of turbine meters shall be sized to remove all particles larger than one-half the distance between the tip of the rotor and the bore of the meter.

11.4 Drip Rings

Drip rings shall be installed between a pair of flanges, one of which may be on a valve, an instrument or a piece of equipment. Typical services for which drip rings shall be installed include:

• In-place field pressurization of relief valves for testing.• Vent/Drain points for close coupled instrumentation.• Drain points on congested piping configurations.


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12.0 SUPPORTS AND ANCHORS

12.1 General

12.1.1 All pipe supports, including "U" bolts, shoes, guides, stops, anchors, restraints, spring hangers, stanchions, base ells, dummy legs, etc., and support structures shall be provided in strict accordance with the Technical Requirements.

CONTRACTOR standards proposed for support design, including piping spacing, shall be submitted to COMPANY for approval prior to implementation.

12.1.2 The basis for pipe supports shall be rigid steel support structure, generally constructed of angles, W-shapes, S-shapes, channel and structural pipe. The basic method for securing piping to the support structure shall be by rigid clamping with “U” bolts that are neoprene coated and double nutted.

CONTRACTOR shall be responsible for determining when other methods of pipe supports are appropriate or necessary. For example, rigid clamping should not be used on high temperature insulated piping, on piping that requires flexibility for imposed movements, or when stresses in the piping system caused by the rigid restraints exceeds the allowable specified in the Technical Requirements.

Use of alternate support methods shall require specific, prior approval of COMPANY in writing.

12.1.3 Wellhead hookup piping from the wellhead to the production manifold shall be supported by spring hangers.

12.1.4 Piping shall be supported to ensure that the stresses shall not exceed the allowable limits in ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping."

12.1.5 Support spacing shall be based on limiting the pipe deflection between supports to the lesser of the following:

• 1/4" for line sizes 2" NPS and smaller, and 1/2" for lines 3" NPS and larger.

• L/500; where L is the span between supports

• Deflection based on one-half the allowable stress value specified in ANSI B31.3 "Chemical Plant and Petroleum Refinery Piping."

The support spacing shall not exceed 15'-0" unless approved by COMPANY.

12.1.6 Small piping shall generally not be supported by adjacent, larger pipes. COMPANY approval is required to support small piping from adjacent piping, and shall be limited to 1-1/2" NPS and smaller lines. If economical, the line size may be increased to eliminate the addition of intermediate supports.


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12.1.7 Piping shall be provided with suitable anchors, guides, stops, sway braces or vibration dampeners to prevent excessive loads, expansion forces and vibration on equipment and vessels.

12.1.8 Both horizontal and vertical piping runs shall be supported at locations of the least vertical movement of the piping.

12.1.9 Supports for riser piping shall be independent of supports for any connected horizontal piping.

12.1.10 Load bearing sleeves on insulated piping shall be of sufficient size and thickness to prevent damage to the insulation material.

12.1.11 Piping stops and anchors shall transmit the entire load directly to the supporting structural member.

12.1.12 Pipe supports at pumps, compressors and drivers shall be attached to structural members capable of withstanding the design loads. The supports, either resilient or fixed supports, guides, stops and anchors shall be attached to a structural member of the equipment skid or the platform. Pipe supports shall not be anchored to equipment baseplates or soleplates.

12.1.13 Adjustable base ell pipe supports shall not be provided unless approved by COMPANY.

12.1.14 CONTRACTOR shall be responsible for ensuring that all FRP piping layouts are properly supported with appropriate flexibility for the intended service. All supports shall be in accordance with the FRP pipe manufacturer's recommendations.

12.1.15 Valves and heavy components in FRP piping systems shall at all times be independently supported or suspended to prevent excessive torque, bending and longitudinal stresses being transmitted to, or carried by the FRP pipe system.

12.2 Support Design

12.2.1 General

12.2.1.1 All pipe supports shall provide positive support to the pipe from below. Pipe supports that provide support from directly overhead, such as rod hangers or "U" bolts clamped or bolted to overhead steel shall not be accepted by COMPANY.

12.2.1.2 Pipe supports shall be designed in accordance with the AISC "Manual of Steel Construction" and AWS D1.1 "Structural Welding Code." Pipe supports shall be designed to be welded to main structural beams of the platform, deck, module


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or skid. Pipe supports shall not rest upon or be supported by grating, deck plate or other non-structural elements.

12.2.1.3 Supports shall be designed to accommodate thermal expansion, contraction and movement of the piping system.

12.2.1.4 Piping supports, guides, stops, anchors and struts shall be designed to withstand the wind and earthquake (transportation) loads specified in the latest edition of ASCE 7-95 "Building Code Requirements for Minimum Design Loads in Buildings and Other Structures." The basic wind speed, exposure and earthquake risk zone (transportation accelerations) shall be in accordance with the Technical Requirements.

12.2.1.5 Pipe supports shall be designed and constructed of standard structural shapes. Pipe-to-pipe fabrication shall not be allowed on pipe supports. Supports shall provide rigid support and sufficient bracing to withstand the vertical loads of the piping and associated equipment. The design shall provide lateral stability sufficient to prevent excessive deflection or horizontal movement.

12.2.1.6 Piping supports shall be designed to facilitate easy removal of the connected equipment, vessels, instrumentation and valves without compromising support for adjacent piping, valves and appurtenances.

12.2.1.7 Pipe supports shall be designed to last the entire service life of the platform.

12.2.1.8 All pipe support column base plates shall be designed in accordance with the AISC "Manual of Steel Construction." Base plates shall be designed for either bolting or welding to the platform support beams.

12.2.1.9 High strength bolted connections shall be designed as bearing type connections with bolt threads in shear planes, but detailed with bolt threads excluded from shear planes. At the point of bolting, all steel members shall have a minimum thickness of 3/8".

12.2.1.10 When specified or required for piping that shifts vertically, variable-load spring hangers shall be provided.

12.2.1.11 If the vertical movement of the piping is excessive, or if the limitations on reactions and stresses is tightly controlled, then the piping shall be supported by constant-load spring hangers.

12.2.1.12 Sizes and types of spring supports shall be selected so that the supports can carry the full design load through a displacement 150% of the calculated displacement.

12.2.1.13 All FRP piping shall be provided with carbon steel saddle type supports that provide 180o of circumferential support. The saddles shall be isolated from the


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FRP pipe by FRP saddles, elastomeric liners, or other materials approved by COMPANY and the FRP pipe manufacturer.

12.2.2 Loads

12.2.2.1 Pipe supports shall be designed to accommodate the dead, live and environmental loadings specified. Dead load shall be defined as the dry weight of the piping system including all pipe, fittings, flanges, valves, instrumentation, insulation, fireproofing, etc. Live loads shall include liquid or solid materials in the piping during normal operation or hydrotesting.

12.2.2.2 In addition to the dead, live and environmental loads, piping supports for risers and riser piping handling two or three phase flow shall be designed to withstand slug flow reaction forces.

12.2.2.3 Wind loading requirements shall comply with API RP 2A "Recommended Practice for Planning, Designing and Constructing Fixed Offshore Platforms." Design loads shall include the two (2) second gust condition as a minimum.

12.2.2.4 Dynamic loading resulting from vibrating equipment and from the surging of fluids in piping shall be considered in the design of all pipe supports.

12.2.2.5 Lateral, torsional, and similar loads caused by piping reactions and transmitted to the pipe support structure shall be considered in the design of the piping supports.

12.2.2.6 The structural design of pipe supports shall consider transportation loads. Design shall be based on loads developed from a barge cargo motion analysis for the specific tow proposed.

12.2.2.7 The final design of a pipe support structure shall be governed by the worst case combination of all possible loads, except that the wind and transportation loads shall not be assumed to act simultaneously.

12.2.3 Stresses

12.2.3.1 Stresses in beams, columns, bracing, and miscellaneous supports shall not exceed the stress allowed in the AISC "Manual of Steel Construction."

12.2.3.2 The AISC allowable stress may be increased by 33% for the transportation design case.

12.3 Materials

12.3.1 Unless specified otherwise, structural shapes, pipe and plate for bolted or welded construction shall be of carbon steel that meets the requirements of ASTM A36 "Specification for Structural Steel." Supports shall be fabricated from materials with a minimum thickness of 3/8".


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12.3.2 Piping supports shall not be fabricated of cast, ductile, or malleable iron.

12.3.3 Piping supports shall be carbon steel for piping systems with design temperatures of 500°F or less. For higher design temperatures, the support material shall be the same material as the piping.

12.3.4 Bolts, nuts, and washers shall be carbon steel conforming to ASTM A325 "Specification for High-Strength Bolts for Structural Steel Joints" with a bichromated cadmium plated coating.

12.3.5 The general method employed to secure uninsulated piping to structural support steel shall be carbon steel "U" bolts with rubber sleeves and double nuts. Neoprene rubber pads, a minimum of 3/8" thick, shall be provided between the pipe and support steel for all pipe 8" NPS and smaller. All "U" bolts and nuts shall be bichromated cadmium plated. Stainless steel "U" bolts may be substituted on stainless steel piping systems.

12.4 Applications

12.4.1 General

12.4.1.1 Pipe supports for CPVC shall be spaced a maximum of 3'-0" apart. A CPVC saddle shall be glued to the underside of the pipe at all support locations. CPVC piping shall not be rigidly anchored to supports; instead, it shall be loosely secured with a broad, smooth hanger to allow pipe movement.

12.4.1.2 Vent and drain systems shall be braced and/or reinforced at all double block and bleed valves.

12.4.1.3 Instrument pressure piping shall be suitably supported and protected from accidental damage. Support methods and details shall be approved by COMPANY.

12.4.2 Supporting Insulated Lines

12.4.2.1 Piping 1-1/2" NPS and smaller shall be supported directly from the insulation by addition of a load-bearing galvanized steel sleeve outside of the insulation.

12.4.2.2 Piping 2" NPS and larger shall be supported on pipe shoe type supports, with the sliding interface between the bottom of the pipe shoe and the support steel. Pipe supports shall be provided with top and bottom saddles that securely clamp to the pipe with bichromated cadmium plated bolting, double nutted. The support design shall allow for the full insulation thickness, and provide a minimum of 1" clearance between the insulation jacket and the support steel.

12.4.2.3 Pipe shoes for insulated hot piping shall include slots to secure the insulation weather proofing jacket with metal straps.


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12.4.3 Supports for Firewater Piping

12.4.3.1 Firewater piping supports shall be designed and constructed to support the weight of the piping system filled with water plus an additional load of 250 pounds applied at each support point.

12.4.3.2 The horizontal distance between hangers and the centerline of an upright sprinkler head shall not be less than 3".

12.4.3.3 The unsupported distance between an end sprinkler head and the last hanger shall not be more than 36" for 1" NPS pipe, or 48" for 1-1/4" NPS and above. If the unsupported distance exceeds the specified limits, piping shall be extended beyond the end sprinkler and supported by an additional hanger.

12.4.3.4 If sprinkler heads are less than 6'-0" apart, hangers shall not be spaced more than 12'-0" apart.

12.4.3.5 Hangers shall not be provided on starter lengths less than 6'-0" long unless the hangers are located at the end of a side-feed system, or if an intermediate cross main hanger is omitted

12.4.3.6 Hangers shall be provided for 1" NPS arms from branch or cross mains if the arms are over 24" long.

12.4.3.7 At least one hanger shall be installed between each two branch lines on cross mains.

12.4.3.8 Risers shall be supported by attachment directly to the riser or by hangers located on the horizontal connection close to the riser.

12.4.4 Supports for Flare System Piping

12.4.4.1 Flare system piping shall be designed, anchored and guided to resist the forward, lateral and upward dynamic forces developed at bends due to high velocity vapors and condensed liquids, as well as to accommodate sudden thermal expansion or contraction. The minimum design values for forces to be restrained shall be as follows:

Nominal Pipe Size: Force: (inches) (tons)

4 0.756 1.58 2.5

10 412 614 716 1018 12


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20 and above 15

12.4.4.2 For pipe supports subjected to stresses resulting from an upset flare relief condition, the AISC allowable stresses may be increased by 33%, but in combination with all other applicable loads.

12.4.5 Supporting Small Lines by Larger Lines

12.4.5.1 Where approved by COMPANY, small lines may be supported from two larger lines by hanging a horizontal structural support member from the larger lines with "U" bolts. The small lines shall be logically grouped to run on the horizontal member between the two larger lines. Supporting small lines from larger lines shall not be approved if the temperature of the supporting piping exceeds 150°F.

12.4.5.2 Tucking small lines under larger lines shall not be accepted.

12.4.5.3 Small lines that branch off from main piping runs preferably shall be routed and supported with other lines unless the shortest direct route is required.

12.4.5.4 If additional support is required, rod type hangers may be provided to avoid supporting the branch line from the above line. The hangers shall be suspended from the horizontal struts between columns. Dummy legs (pipe extensions) from elbows may be used to reach beams or brackets beyond the turn with COMPANY approval.

12.4.6 Supports for Hydrostatic Testing

12.4.6.1 All piping and supports shall be designed for the loads developed during hydrostatic testing. Temporary supports shall be allowed only if approved in writing by COMPANY.

12.4.6.2 Supports for large lines may be designed for pneumatic testing only if approved in writing by COMPANY.

12.4.6.3 Springs and lever arms shall be protected against overload during hydrostatic testing. Restraints or stops installed for testing shall be removed immediately after testing has been satisfactorily completed.

12.5 Spring Supports

12.5.1 General

12.5.1.1 Spring supports shall be capable of supporting the pipe under all operating conditions and shall allow free expansion and contraction of the piping.

12.5.1.2 Spring supports shall prevent excessive stress induced by transfer of weight to the pipe or connected equipment.


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12.5.1.3 Supports and parts shall conform to the latest requirements of MSS SP 58 "Materials, Design and Manufacture of Pipe Hangers and Supports," and MSS SP 69 "Selection and Application of Pipe Hangers and Supports," except as supplemented or modified by the Technical Requirements.

12.5.2 Variable-Load Supports

12.5.2.1 When spring supports are specified or required, variable-load spring hangers shall be provided unless the vertical movement of the piping or the additional stress due to load fluctuations require the use of constant-load spring hangers.

12.5.2.2 Variable spring supports shall be furnished with travel stops. The travel stops shall be factory installed so that the piston cap is set at the cold position. The travel stop shall be easily removable, but capable of acting as a rigid hanger during erection.

12.5.3 Constant-Load Supports

12.5.3.1 When spring supports are specified or required, and the vertical movement of the piping or the stress of load fluctuations makes variable-load supports unsuitable, then constant-load supports shall be provided.

12.5.3.2 Constant-load supports shall be installed with travel stops. The travel stops shall be factory installed so that the hanger level is at the cold position. The travel stops shall permit future re-engagement without making hanger rod adjustments even if the lever is not in the cold position.

12.5.3.3 Constant-load supports shall provide a means of vertical adjustment after erection.

12.5.4 Provisions for Lateral and Axial Movement

12.5.4.1 Hanger rod type spring supports shall require COMPANY approval.

12.5.4.2 Hanger rods shall be subjected to tensile loading only. Linkages to permit swing shall be provided at hanger locations where lateral or axial movement is anticipated.

12.5.4.3 If the horizontal movement between the cold and hot positions of piping is such that the hanger rod is more than 4o from the vertical during operation of the piping system, pipe hangers and structural attachments shall be offset so that the rod is vertical during operation.

12.5.4.4 Hangers shall be designed so that the hangers cannot become disengaged by movement of the supported pipe.


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12.6 Dummy Supports

12.6.1 Dummy supports (legs) shall generally not be utilized except when approved by COMPANY on a case by case basis. When approved, dummy supports shall be in accordance with the Technical Requirements defined herein.

12.6.2 Dummy supports on stainless steel or heat treated carbon steel lines shall be of the same material as the pipe, at least up to the first dummy support field weld. The remaining portion of the dummy support may be carbon steel.

12.6.3 Dummy supports on insulated lines shall be insulated to a distance from the pipe weld a minimum of four times the line insulation thickness, or 9", whichever is greater.

12.6.4 Dummy supports longer than 6'-0" shall be an engineered item, including calculation of mechanical stresses to size the support pipe.

12.6.5 The terminating end of dummy supports shall be capped, and weep holes provided on each end of the support.

13.0 DOCUMENTATION REQUIREMENTS

13.1 General

13.1.1 CONTRACTOR shall utilize industry standard drawing practices as a minimum in executing the work. For instance, all drawings shall utilize title blocks and revision blocks for drawing identification and control. All drawings shall be dated and signed by appropriate CONTRACTOR representatives. When revised, CONTRACTOR shall identify revisions on drawings with clouds and revision triangles, and the title and revision blocks shall be appropriately completed with descriptions, dates and signatures.

13.1.2 CONTRACTOR shall provide to COMPANY a document index detailing all drawings and their proposed submittal schedule within 2 weeks of Contract, Agreement, or Purchase Order award, as applicable.

13.1.3 The following information shall be included on piping drawings as a minimum:

a. Project Title and Contract, Agreement or Purchase Order Number

b. Reference to COMPANY-supplied drawings, if applicable

c. Completed Title Block

d. Key map with Platform North Arrow

e. Revision clouds and numbered revision triangles

f. Elevation, Section and Detail Callouts, including sheet references

g. Piping Line Numbers, Valve Codes and Specialty Item Numbers


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h. Detailed fabrication dimensions

i. Weld symbols and Weld Procedure Specification (WPS) numbers

j. Field weld locations

k. Isometric, spool or piece mark numbers (Isometric or spool drawings only)

l. Bill of Materials with quantity, size and complete material descriptions (Isometric or spool drawings only)

13.1.4 Piping drawings shall show complete assembly and installation details for all piping except piping mounted on skid packages.

13.1.5 Piping drawings shall show all components required for fabrication, including instrument installation points and the interconnecting points for all vents, drains and purge points.

13.1.6 Piping drawings shall show all vessel and equipment direct connection points. Connections to vessels and equipment shall be labeled to agree with CONTRACTOR or CONTRACTOR drawings.

13.1.7 All valves, insulation, anchors, guides, shoes, instruments, and their ancillary components shall be depicted in piping drawings.

13.1.8 Arrows shall be drawn on piping centerlines to indicate the direction of flow.

13.2 Piping Plans

Piping plan drawings shall be prepared providing all information necessary for fabrication and assembly of piping systems. Drawings shall also contain enough detail to allow for planning of work during offshore hookup and commissioning. Namely, all offshore field welds shall be identified.

13.3 Elevations and Sections

Elevations and sections shall be provided to clarify the piping plans, in particular the assembly between piping and equipment or vessels.

13.4 Details

Enlarged views and details shall be generated as necessary to illustrate, explain and confirm full details and clearances at intersections, congested areas or where several lines converge. All details necessary for full clarity shall be provided.

13.5 Isometrics

Isometric drawings shall be the primary piping drawings used during pipe spool fabrication. Isometric drawings shall show a single-line, no-scale isometric view of a single piping service, or portion thereof. All field welds shall be identified. All


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materials required by an isometric drawing shall be recorded in the material blanks provided on a standard isometric drawing sheet.


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APPENDIX I

MANDATORY CODES AND STANDARDS

American Institute of Steel Construction (AISC)

Manual of Steel Construction

American National Standards Institute (ANSI)

B16.5 Pipe Flanges and Flanged FittingsB31.2 Fuel Gas PipingB31.3 Chemical Plant and Petroleum Refinery PipingB73.1 Specification for Horizontal End Suction Centrifugal Pumps for Chemical

ProcessB73.2 Specification for Vertical In-Line Centrifugal Pumps for Chemical Process

American Petroleum Institute (API)

RP 2A Planning, Designing and Constructing Fixed Offshore PlatformsRP 14C Analysis, Design, Installation and Testing of Basic Surface Safety Systems on

Offshore Production PlatformsRP 14E Design and Installation of Offshore Production Platform Piping SystemsRP 520 Sizing, Selection and Installation of Pressure-Relieving Devices in Refineries,

Part II - InstallationRP 521 Guide for Pressure-Relieving and Depressuring SystemsRP 550 Manual for Installation of Refinery Instruments and Control SystemsSPEC 6A Specification for Wellhead EquipmentSPEC 6D Specification for Pipeline Valves, End Closures, Connectors and SwivelsSTD 607 Fire Test for Soft-Seated Ball ValvesSTD 610 Centrifugal Pumps for General Refinery ServiceSTD 611 General-Purpose Steam Turbines for Refinery ServiceSTD 612 Special-Purpose Steam Turbines for Refinery ServiceSTD 614 Lubrication, Shaft-Sealing and Control Oil Systems for Special-Purpose

ApplicationsSTD 616 Combustion Gas Turbines for General Refinery ServicesSTD 617 Centrifugal Compressors for General Refinery Services

STD 618 Reciprocating Compressors for General Refinery ServicesSTD 674 Reciprocating PumpsSTD 1101 Manual of Petroleum Measurement StandardsSTD 2531 Manual of Petroleum Measurement StandardsSTD 2534 Manual of Petroleum Measurement Standards


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APPENDIX I - (Continued)

MANDATORY CODES AND STANDARDS

American Society of Civil Engineers (ASCE)

7-95 Building Code Requirements for Minimum Design Loads in Buildings and Other Structures

American Society for Testing and Materials (ASTM)

A36 Specification for Structural SteelA325 Specification for High-Strength Bolts for Structural Steel JointsD2846 Specification for Chlorinated Poly Vinyl Chloride (CPVC) Plastic Hot- and Cold-

Water Distribution SystemsF492 Propylene and Polypropylene (PP) Plastic-Lined Ferrous Metal Pipe and Fittings

American Welding Society (AWS)

D1.1 Structural Welding Code

Instrument Society of America (ISA)

RP 4.2 Standard Control Valve Manifold Designs

Manufacturers Standardization Society of Valve Fittings Industry (MSS)

SP 69 Selection and Application of Pipe Hangers and Supports

National Association of Corrosion Engineers (NACE)

MR-01-75 Sulfide Stress Cracking Resistant Metallic Material for Oil Field EquipmentRP 07 Preparation and Installation of Corrosion Coupons and Interpretation of Test

Data in Oil Production Practice

National Electrical Manufacturers Association (NEMA)

SM 23 Steam Turbines for Mechanical Drive Service

National Fire Protection Association (NFPA)

11 Low Expansion Foam and Combined Agent Systems12 CO2 Extinguishing Systems37 Standard for the Installation and Use of Stationary Combustion Engines and

Gas Turbines54 National Fuel Gas Code


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APPENDIX II

GOVERNMENT AGENCIES

United States Department of the Interior - Minerals Management Service (MMS)

Outer Continental Shelf Order No. 5


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APPENDIX III

CHEVRON STANDARDS

GO-590 Chevron "Safety in Designs" (SID) Manual

Chevron Standard Drawings:

GD-L1050-2 Piping Standard for Sizes and Locations of Jack Screws in Flanges and Exchanger Feet

GF-L14298-9 Standard Assembly and Details of Blanks and Special Rings for Class 150, 300, 600, 900, 1500 and 2500 Ring Joints

GC-L31452-22 Standard Figure 8 Blank (Spectacle), Paddle Spacers, and Paddle Blanks for Raised Face Flanges

GB-L88612-7 Standard Conical Temporary Pump Suction ScreensGB-L99961-6 Standard Valve Installation Guide


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