SY/T 10042-2002 Recommended Practice for Design and Installation of Piping Systems on Offshore Production Platforms
Some standard content:
SY/T 10042—2002
To meet the needs of developing offshore oil and gas resources in my country, China National Offshore Oil Corporation Shishan adopted the fifth edition of API RP14F "Recommcnded Practice for Design and Installation of Offshore Production Platform Piping Systems" 1991 (including the revision of the fourth edition adopted at the standardization meeting in 1990) of the American Petroleum Institute, and revised the original SYT480992 "Recommended Practice for Design and Installation of Offshore Production Platform Piping Systems" which was equivalent to API RP14E:1984, and published it as a new oil and gas industry standard. If there is any objection to the translation of the standard, the original text of the adopted standard shall prevail. This revision makes its meaning more accurate, the content more complete, and easier for users to understand. Compared with the previous version, the following chapters of this standard have been significantly modified, and some new contents have been added: Chapter 1, 1.7 "Considerations on Corrosion"; Chapter 2, 2.1 "Pipeline Class", 2.2 "Overview of Dimensioning Principles", 2.4 "Criteria for Determining the Size of Single-Phase Gas Pipelines", 2.5 "Criteria for Determining the Size of Gas/Liquid Dual-Phase Pipelines", 2.6 "Pipeline Wall Thickness"; Chapter 3, 3.2 "Valve Types"; Chapter 4, 4.5 "Flanges"; Chapter 5, 5.8 "Pressure Relief and Treatment Systems", 5.9 "Discharge Systems": Other chapters have also been modified, adjusted, added, and deleted. For details, see the end text.
To facilitate users to consult the original text, except for the three obvious inappropriate places that were modified according to the requirements of GB/T1.1, the Chinese layout is basically the same as the original text and has not been changed.
In the design, construction and use of offshore oil and natural gas development projects, the government of the country where the original standard is located is involved. Or other laws, regulations and provisions of competent authorities, they shall be implemented in accordance with the corresponding laws, regulations and provisions promulgated by the Government of the People's Republic of China or government departments in charge. The data or quantitative calculation methods of environmental conditions such as wind, waves, currents, ice, temperature, ground dew, etc. in the original standard can be used as a reference if they are in line with my country's actual conditions: otherwise, the data and calculation methods that are in line with my country's actual environmental conditions shall be used. Regarding the expression of measurement units, my country's legal measurement units shall be the main ones. That is, the legal measurement unit value is in front, and the corresponding value of the imperial unit is marked in brackets after it:
In order not to change the formula in the original standard and maintain the shape characteristics of the curve, the imperial units originally used in the formula and curve have not been changed. This standard will replace SY/T4809--92 from the date of its entry into force. Appendices A, B and C of this standard are normative appendices, and Appendices D, E and F are informative appendices. This standard is provided by China Tonghai Marine Stone Co., Ltd. The standard was proposed and managed by China National Offshore Oil Corporation. This standard was compiled by the Development and Design Institute of the Research Center of China National Offshore Oil Corporation: The main compiler of this standard is Zhu Haishan.
The chief reviewer of this standard is Zhao Yingnian.
The previous versions of the standards replaced by this standard are: SY/T4809—92m
AP[Foreword
Special statement
Symbols·
Chapter 1 General provisions||tt| |1.1 Scope
1.2 Pressure Piping Code
1.3 Policy Specifications (Omitted)
1.4 Industry Regulations, Guidelines and Standards
1.5 Government Regulations and Laws
1.6 Classification of Systems by Pressure Classes.7 Considerations for Corrosion
Chapter 2 Piping Design
2.1 Piping Classes
2.2 Criteria for Sizing
|Overview·
2.3 Criteria for Sizing Liquid Pipelines...
2.4 Criteria for Sizing Single-Phase Gas Pipelines. 2.5 Criteria for Sizing Gas/Liquid Dual-Phase Pipelines. 2.6 Pipeline Wall Thickness
2.8 Expansion and Deflection·
2.9 Start-up Facilities
2.10 References (Omitted)
Chapter 3 Valve Selection
3.1Overview·
3. 2 Types of valves
3.3 Determination of valve size
3.4 Pressure and temperature ratings of valves
3.5 Valve materials
3.6 References (omitted)
Chapter 4 Pipe fittings and flanges
4.1 Overview
Welded pipe fittings
Threaded pipe fittings
4.4 Branch pipe connections
Special connectors
SY/T 10042—2002
SY/T10042—2002
4.7 Special requirements for sulfide stress cracking operations 4.8 Erosion protection.
4.9 References (omitted)
Chapter 5 Design considerations for special piping systems
5.1 Overview-
5.2 Wellhead accessories
5.3 Discharge manifolds and accessories
5.4 Production manifolds...·
5.5 Processing vessel accessories
5.6 Utility systems 5.7 Heating fluid and alcohol system 5.8 Pressure relief and treatment system 5.9 Discharge system 5.10 Trestle piping between platforms 5.11 Riser 5.12 Sampling valve 5.13 References (omitted) Chapter 6, consideration of related items 6.1 Overview 6.2 Layout 6.3 Elevation 6.4 Pipe supports 6.5 Others Corrosion considerations
6.6 Insulation·
Noise·
Table of pipes, valves and fittings·
6.9 Inspection, maintenance and repair·
Chapter 7 Installation and quality control
7.1 Overview
7.2 Qualified inspectors
7.3 Welding
7.4 Pressure test
7.5 Pressure test records
Appendix A (Normative Appendix) Examples
Appendix B (Normative Appendix) Applicable to the butt joint of pipes with the same wall thickness Appendix C (normative appendix)
Tables for pipes, valves and pipes
Appendix D (informative appendix)
Formula search
Appendix E (informative appendix)
Appendix F (informative appendix)
Index of illustrations
Table index
SY/T10042—2002
API Foreword
a) This law practice (RP) is managed by the Marine Safety and Pollution Prevention Equipment Standardization Committee of the American Petroleum Institute (APD). It was developed under the comprehensive consultation and guidance of the American Petroleum Institute (API), the Offshore Operators Committee (OOC) and the Western Oil and Gas Association (WOGA). The chapters on corrosion were developed with the help of the National Association of Corrosion Engineers (NACE). b) This RP contains information intended primarily for use by design engineers with some experience in production machine operations. Some of the information may be useful to experienced operators: Nothing in this RP should be construed as a set of rules not relevant to a complete engineering evaluation, nor is it intended to override or supersede applicable federal, state, or local regulations. c) To increase clarity of figures and empirical formulas, the conversion of English units to International System of Units (SI) has been deleted. The factors that may be used in the conversion of English units to International System of Units are referenced from API Publication 2564 and are listed below: Length
inches (in) = 25.4 millimeters (mn) Exact Value Pressure
1 pound/inch2 (psi) 0.06894757 bar (:ar): {Bar (Bar) = 1 0 Pa (ka)
Strength or stress
1 pound/inch2 (psi) = 0.006894757 megapascals (MPa) Kinetic energy
1 foot pound ("·h) = 1.355818 joules H (J) Torque
1 foot pound (ftIb) = 1.355818 Newton meter (N*m) Temperature
The conversion from Fahrenheit (F) to Celsius (℃) uses the following formula: = 5/9 ('F - 32)
1 cubic foot (ft) = 0.02831685 cubic meter (m3)1 gallon (gal) = 0.003785412 cubic meter (m)1 barrel (bl) = 0.1589873 cubic meter (m)Weight
1 pound (16) = 0,4535924 kilograms (kg)Force
1 pound (b) — 4.448222 Newtons (N)
1 barrel/day (bhl/d) = 0.1589873 cubic meters/day (m3/d) 1 cubic centimeter/minute (cf/min) - 40.77626 cubic meters/day (m/d) Offshore production platform pipeline system
Recommended practice for design and installation
SY/F10042-2002
The following definitions apply specifically to the equipment and systems described in this recommended practice (RP): Chloride stress cracking service: The processed fluid contains water and chlorides and reaches a concentration and temperature sufficient to cause stress cracking of iron-based alloy materials. The presence of other components such as oxygen (O) may accelerate this chloride stress cracking.
Choke: A device specifically used to control the flow of fluids. Corrosion-erosion: A phenomenon in which a protective film formed by rust is eroded by the erosion of the processed fluid, and the exposed new metal surface is corroded. Under the repeated action of this phenomenon, very serious metal weight loss may occur.
Corrosive Gas: Gas that causes metal corrosion when dissolved in water or other liquids, usually including chlorine sulfide (H2), carbon dioxide (CO2) and oxygen ((2). Corrosive Hydrocarbon Service: Logistics operations that handle water or seawater and carbon dioxide ((X), oxygen (O) or other corrosive media under conditions that can cause metal weight loss. Design Pressure: The maximum allowable working pressure at the design temperature. Expansion Bellows: A bellows designed to absorb expansion and contraction: Expansion Bend: A pipe designed to absorb expansion and contraction, Fire Watch: During welding or burning, one or more trained personnel carrying practical fire-fighting equipment stand there to guard.
Flowline: A pipeline that transports fluid from a parallel port to a manifold or a Pipes for containers at the stage. Flow regime: The flow conditions of multiphase flow, such as slug flow, mist flow or stratified flow. Fluid: A general term for a natural gas, steam, liquid or a mixture thereof. Header: The part of the manifold that directs the fluid to a dedicated treatment system (Figure 5.1A). Hydrocarbon wettability: The ability of the treated flow to form a protective hydrocarbon film on the metal surface. Manifold: An assembly of pipes, valves and fittings that selectively directs flow from one or more sources to various treatment systems.
Nipple: A threaded or welded pipe section less than 30.48 cm (12 in) in length used as an accessory. Non-Corrxive Hydrocarbon Service: The operation of handling flows that do not cause significant metal weight loss, local chemical reactions or stress corrosion damage. Platform pipeline (Platform) Piping: A general term for various pipes that load and transport fluids on a platform. Pressure Sensor: A component designed to detect a preset pressure. Process Unit: A set of single-function equipment and auxiliary pipes, such as pressure vessels, heaters, pumps, etc. Riser: The vertical part of the submarine pipeline that reaches or leaves the platform (including the bottom pipe): Shutdown Valve: A valve used to isolate the automatic operation of processing equipment or processing systems. Sulfide Stress Cracking Service: The operation of handling logistics containing water, brine and hydrogen sulfide (HS) with concentrations sufficient to cause stress cracking of sensitive materials. Wellhead Pressure: The maximum ground shut-in pressure that may occur in an oil well. SY/T 10042—2002
The following symbols apply to the formulas in this recommended practice (RP): A—Minimum cross-sectional flow area of the pipe required to flow 1000 bbl of fluid per day, in?; B—Average coefficient of thermal expansion at normal operating temperature, in/in/\F: C—Pump empirical constant;
C—Empirical constant: wwW.bzxz.Net
C—Valve coefficient [the amount of water flowing through the valve per minute when the pressure drop is 1 lb/in2 (psi) at 60F], GPMl: d—Inside diameter of pipe, ft
d;—Inside diameter of pipe, in;
Nominal diameter of pipe, in;
D,——Outside diameter of pipe, in:
E—Longitudinal weld coefficient, dimensionless;
Em—Modulus of elasticity of the pipe material under cold conditions, psi; — friction coefficient, dimensionless;
universal gravitational constant, fi/2:
- liquid flow rate, gal/min;
h. - gravity acceleration head, feet of liquid column; friction head, feet of liquid column:
- absolute head, feet of liquid column;
static head, feet of liquid column;
velocity head, feet of liquid column;
hvp—absolute vapor pressure, feet of liquid column:
Ahw—static head pressure difference, inches of water column:- acceleration coefficient, dimensionless;
L—pipeline length, ft,
Af—extension of the pipeline, in
MPSH net positive suction head, feet of liquid column; p—operating pressure, (b/in2 (absolute pressure, psi) p—internal design pressure, b/in (gauge pressure: si); Ap— —Pressure drop, lb/in2 (psi);
Ap——Pressure drop, Ib/in2/100ft;
Q. —Gas flow, 10°ft/a14.7lb/in2 (absolute pressure and 60°F conditions]; Qt—Liquid flow, bl/d;
-Gas flow, ft/h [14.7lb/n2 (absolute pressure and 60\F conditions] Gas/liquid ratio, standard ft3/bbl;
Reynolds number, dimensionless;
Pump speed, r/min;
Gas density at operating pressure and temperature, 1b/ff; Pa
The article also uses "flow pressure, Ih/in- (absolute non-force)\.2
pt—Body density at operating temperature, lb/tr; PmGas at operating pressure and temperature / liquid mixture density, Ib/t*; S---allowable stress, lb/in2 (psi); S--gas relative density (air = 1); S,--liquid relative density (water = 1);
T--operating temperature.RO;
design pressure bearing thickness, in;
-temperature change, F;
support point spacing, f (straight-line distance between two support points); gas viscosity under flow pressure and temperature conditions, cP; liquid viscosity, lb/ft's;
fluid erosion velocity, ft/s;
average gas velocity, ft/se;
average liquid velocity, ft/s;
W--total flow rate of liquid and steam, lb/h;Y--temperature coefficient, dimensionless:
Z--gas compressibility coefficient, dimensionless.
Chapter 1 General
SY/T 10042—2002
1.1 Scope
This recommended practice recommends minimum requirements and guidelines for the design and installation of new offshore production semi-trailer piping systems. The maximum design pressure in this article is 70,000 kPa (10,000 Jsi) and the temperature range is 29 (-20F) to 343°C (650°F). For applications outside this pressure and temperature range, special consideration should be given to material properties (such as ductility, carburization, etc.). This recommended practice is based on many years of experience in developing offshore gas fields. Virtually all of this offshore experience has been used in hydrocarbon operations without hydrogen sulfide. However, the recommended practice, which is based on extensive onshore experience, also includes certain aspects of hydrocarbon operations containing hydrogen sulfide. a) This recommended practice includes general requirements and specific requirements for topside facility piping systems that are not detailed in API Spec 6A. Chapters 2, 3 and 4 are general requirements for the design and application of pipes, valves and fittings for typical process flows. Chapters 6 and 7 are general requirements for installation, quality control, and matters related to typical process flow piping systems, such as general requirements for insulation. Chapter 5 is specific requirements for the design of special piping systems, which includes piping systems that differ from the recommended practices in the general chapters.
6) Carbon steel materials are suitable for most production platform piping systems. At least one of the recommended carbon steel materials is the most commonly used. Other materials that may be suitable for platform piping systems are not included because they are generally not used. When selecting materials other than these recommended practices, the following aspects should be considered: (1) Type of operation.
(2) Compatibility with other materials
(3) Ductility
(4) Requirements for special welding procedures,
(5) Requirements for special inspection, testing or quality control. (6) Possible misuse on site.
0 The article sometimes uses "flow temperature, \R\". @ The article sometimes uses "body velocity, ft/s" 3
SY/T 1042—2002
(7) Corrosion and erosion caused by internal fluid and/or marine environment, 1.2 Pressure Piping Code
Herein, it is defined that the design and installation of platform pipelines shall comply with ANSIB31.3. For those that cannot comply with B31.3, the following practices shall be followed for design and installation:
a) Design, construction, inspection and testing shall be in accordance with ANSIB31.4, B31.8 and the applicable parts of Section 192 and/or Section 195 of Chapter 49 of the Code of Federal Regulations (CFR). The design stress used shall not exceed 0.6 times the specified minimum yield strength (SMYS).
5) It is required to conduct 100% radiographic inspection of welds in accordance with APIStd1104. ) For pipes with a rating higher than X-52, an impact test for the lowest expected operating temperature shall be required. d) Valves, fittings and flanges may be manufactured in accordance with the standards of the Manufacturers Standardization Society (MSS) of the valve and fittings industry. The pressure/temperature ratings and material suitability shall be checked. e) When determining the limits of the riser and platform pipelines, the shut-off valves where the fluid first enters the platform and the last leaves the platform are the limits of this recommended practice. The recommended practice in this article can be used for the riser design after considering factors such as water depth, inclination of the platform legs, and possible splash zones.
1.3 Policy Statement (omitted)
1.4 Industry Regulations, Guides and Standards
Many regulations, guidelines and standards have been proposed by different organizations and are currently accepted by industry and government departments. The regulations referenced here are listed below. Guides and Standards The referenced standards listed in this article refer to the latest edition unless otherwise stated. a) American Iron and Steel Institute (AISI): AISI Steel Products Manual Stainless Steel and Heat Resisting Steels (ANSI Steel Products Manual, Stainless Steel and Heat Resisting Steels.) b) American National Standards Institute (ANSI) (formerly "ASA" and "USAS"): (1) ANSIB 2.1 Pipe Threads (ANSI IR 2.1, Pipe Thr cads.) (2) ANSIB 16.5 Steel Pipu Flanges, Flanged Valves, and Fittings (ANS[B16.5. Steel Pipu Flanges, Flanged Valves, and Fittings.) (3) AVSIB 16.9 Factory-Made Wrought Steel Burt Welding Fittings (4) AVSIB 16.10 Face-Face and End Dimensions of Ferrous Valvcs. (5) AVSIB 16.11 Forged Steel Fittings, Socket-Welded Fittings and Threaded Fittings (6) AASIB 16.28 Wrought Steel Butt-Welded Short Radius Elbows and U-Bends (ANSI B 16.28 Wrought Steel Butt-Welded Short Radius Elbows and Rerurns. (7) ANSIB31.3 "Pet. role Refinery Piping." (8) A.vSIH31.4 "Oil Transportation Piping." (9) ANSI B31.8 "Gas Transmission and Distribution Piping System." (10) ANSTF36.10 "Wrought-Steeland Wrought Iron Pipe." (AVSIB36.10) (c) American Petroleum Institute API: (1) APIRP2G "Remended Practice for Production Facilities on Cffshore Siructures." 4 (1) APIRP2G "Remended Practice for Production Facilities on Cffshore Siructures." 10042—2002
(2) API Bull5A2 "Bulletin (on Thread Corpounds for Csing, Tubing, and Line: Pipe." (3) API SpecSB "Specification for Thrcarling, Gaging, and Thread Inspection of Casing, Tubing. and LimFipe Threards." (4) API Spec 5L "Specification for Linc Fipe." (5) API Spec 6A "Specification for Wellhead Equipment." (6) API Spec 6D "Specification for Pipeline Valves." Valvcs.) (7) APIRP 14C: Recommended Practice for Annlysis. Design, Inseillation and Testing of HBasicSurface Safety Syslern for Offshore Production Pla forms.) (8) API R I510 "Pressure Vessel Inspection Code" (APRP510, P'ressure Vessel Inspection Code.) (9) API R P520 "Refining! (10) API RP521, Guide for Pressure Relieving and Depressurizing System. (11) API Std 526, Flanged Steel Safety Relief Valves. (12) API RP550, Manual on Installation of Refinery Instrument and Control Systems, Parts I and II. II.) (13) API Std 600 "Steel Gate Valves (Flanged or Butiwclding Ends)" (API Std 600, Steel Gare Valves (Flanged or Butiwclding Ends).)
(14) API Std 602 "Compact Carbon Steel Gate Valves for Refining Lise (Cormpact Design).) (15) API Std 1104 "Welding Standard for Pipelines and Related Facilities" (API Std 1104, Standard lurWcldling pipelines and Related Facilities.) (16) API Medical Research Report FA7301 "Guidelines for Noise" (API Medical Research Report FA7301 Guidelines an Neise.)
d) American Society for Testing and Materials ASTM:
(I) ASTM A53 "Specification for Welded and Seamless Steel Pipe." (2) ASTM A105 "Specification for Forgings, Carbon Steel, for Piping (omponents.)" (3) ASTM A106 "Specification for Seamluws Carbon Steel Fipe for High -\I'ernpcrature Services." (4) ASTM A153 "Specification for Zinc Coating-ing (Hat-Tip) on Iron and Steel" (5) ASTM A193 "Specification for Alloy Steel and Stainlcss Steel Bolting Materials for High -Ternperature: Service. (6) ASTM A194 "Specification for Carbon and Allcy Steel Nuts for Bolts for High -Ptussure and High -Tem-SY/T 10042—20H02
ptraturc Service. (7) ASTM A234 "Specification for Piping Fittings of Wrought Carbon Steel and Alloy Steel for Modlerate awElevaled (8) ASTM A333 "Seamless and Welded Steel Pipe for Low-Temperature Service" (ASTM A333, Specification for Seamless and Welded Steel Pipe for Low-Temperature Service.) (9) ASIMA354 "Specification for Quenched and Tempered Alloy Steel Bolts, Studs, and Other Externally Threaded Fasteners." c) American Society of Mechanical Engineers ASME: (1) ASME "Boiler and Pressure Vessel Code" Section IV "Heating" (ASME Boiler and Pressure Vessel Code Section IW, Heating.) (2) ASMF "Boiler and Pressure Vessel Code" Section 1 "Pressure Vessel" (ASME Boiler and Pressure Vessel Code Section 2 "Pressure Vessel" Part 3 "Pressure Vessel" (3) ASME Boiler and Pressure Vessel Code, Section X, Qualification Standard for Welding and Brazing Procedures, Weiders Brazers, and Welding and Brazing Operators.) (United States) National Association of Pressure Engineers (NACE): (1) NACE StIMR-01-75, Sulide Strcxs Cracking Resistant Metallic Material for Oil Field Equipment (2) NACE Std RP-O1-76, Corrosion Control on Steel, Fixed Offshorc Platforms Associated with Petoleum Prxluclicn. (2) NACE Std RP-O1-76, Corrosion Control on Steel, Fixed Offshorc Platforms Associated with Petoleum Prxluclicn. (2) NACE Std RP-O1-76, Corrosion Control on Steel, Fixed Offshorc Platforms Associated with Petoleum Prxluclicn. (2) NACE Std RP-O1-76, Corrosion Control on Steel, Fixed Offshorc Platforms Associated with Petoleum Prxluclicn. (2) NACE Std RP-O1-76, Corrosion Control on Steel, Fixed Offshorc Platforms Associated with Petoleum Prxluclicn. (2) National Fire Protection Association NFPA: (1) National Fire Code Volume 6, Sprinklers, Fire Punps and Water Tanks.(2) National Fire Code, Volume 8 Portable and Manual Fire Fighting Equipment (onirol Faquiprrerut.) h) Natural Gas Processing Suppliers Association GPSA (formerly NGHSA) Engineering Data Books. i) Hydraulics Society:
(1) Standards for Centrifugal: Rotary and Reciprocating Pumps.
(2) Pipe Friction Manual. 1.5 Government Regulations and Rules
Regulatory agencies have established certain regulations and rules that may affect the nature and manner of platform pipeline installation and operation. Mentioned below are the important rules and regulations newly listed in the original text of API14E that should be paid attention to in the design and installation of pipelines (users of this specification should refer to the relevant national and local rules and regulations of the People's Republic of China). a) Federal regulations: (1) Title 29, Section 1910, Occupational Safety and Health Standards. (2) Title 30, Section 250, Oil and Gas Mining and Sulphur Operations in the Outer Continental Shelf (SY/T 10042--2002) (3) Title 33 Subchapter C, Aids to Navigation, Part 67, Aids on Navigation on Artificial Islands and Fixed Structures. (4) Title 33, Subchapter N, Artficia. Islands ard Fixed Structures on the Outer Continental Shelf, Part 140thnugh146. (5) Title 33, Part 153, Control of F'olluition by Oil and Hazardous Substances, Discharge Removal （6）Title 40, Part 110, Discharge of Oil. （7）Title 40, Part 112, Cil Pollution Prevention. （8）Title 49, Part 192, Minimum Federal Safety Standards for Natural and Other Gas by Pipeline: Mirirmurn Federal Safety Standards for Natural and Other Gas by Pipeline Standards.
(9) Title: 49, Part 195, Transportation of Liquids by Pipeline.
b) Environmental Protection Agency: Document AP-26, Workbook on Atmospheric Dispersion Estinates.
c) Regional Outer (Ontincnlal Shelf) Orders Promulgated under the Code of Federal Regulations, Title 3, Part 25n, Oil and Gas and Sulphur Operations in the Outer Continerual Shelf.
d) Regulations of state, municipal, and other local regulatory agencies also apply. 1.6 Classification of systems by pressure levels Usually, the pressure of the gas stream is gradually reduced after it leaves the wellhead. After the pressure is reduced, the process equipment with lower pressure levels can be used. Figure 1.1 is a typical example. a) A rule for the design of pressure devices is that any pressure-bearing component should be designed to withstand the highest pressure acting on it under any condition, or it should be protected by a pressure relief device. In this case, the pressure relief device is a safety relief valve or a safety disk: Generally speaking, when determining the need for a pressure relief device, the use of high-pressure shut-off valves, non-return valves, control valves or other similar devices to prevent overpressure of the process equipment should not be considered. For the recommended safety devices required for the process equipment, refer to API RP14Cc
b. A good way to analyze the required system design pressure level for the process equipment is to draw the pressure level boundaries in the equipment process flow diagram. In this way, each device (vessel, flange, pipeline or accessory) can be checked to determine whether it is either designed to withstand the highest pressure or protected by a pressure relief device. 1.7 Consideration of corrosion
a) Overview:
Detailed anti-corrosion practices for platform piping systems are not within the scope of this recommended practice. These practices are generally developed by anti-corrosion experts. However, the design of platform piping systems should adopt and comply with the following anti-corrosion practices. Some suggestions on anti-corrosion materials and corrosion mitigation are given in the corresponding chapters of this recommended practice.
: The corrosiveness of the processed fluid may change over time, and the possibility of changing conditions should be considered during the design stage. b. Weight loss corrosion(4) Title 33, Subchapter N, Artficia. Islands and Fixed Structures on the Outer Continental Shelf, Part 140th through 146. (5) Title 33, Part 153, Control of Pollution by Oil and Hazardous Substances, Discharge Removal （6）Title 40, Part 110, Discharge of Oil. （7）Title 40, Part 112, Cil Pollution Prevention. （8）Title 49, Part 192, Minimum Federal Safety Standards for Natural and Other Gas by Pipeline: Mirirmurn Federal Safety Standards for Natural and Other Gas by Pipeline Standards.
(9) Title: 49, Part 195, Transportation of Liquids by Pipeline.
b) Environmental Protection Agency: Document AP-26, Workbook on Atmospheric Dispersion Estinates.
c) Regional Outer (Ontincnlal Shelf) Orders Promulgated under the Code of Federal Regulations, Title 3, Part 25n, Oil and Gas and Sulphur Operations in the Outer Continerual Shelf.
d) Regulations of state, municipal, and other local regulatory agencies also apply. 1.6 Classification of systems by pressure levels Usually, the pressure of the gas stream is gradually reduced after it leaves the wellhead. After the pressure is reduced, the process equipment with lower pressure levels can be used. Figure 1.1 is a typical example. a) A rule for the design of pressure devices is that any pressure-bearing component should be designed to withstand the highest pressure acting on it under any condition, or it should be protected by a pressure relief device. In this case, the pressure relief device is a safety relief valve or a safety disk: Generally speaking, when determining the need for a pressure relief device, the use of high-pressure shut-off valves, non-return valves, control valves or other similar devices to prevent overpressure of the process equipment should not be considered. For the recommended safety devices required for the process equipment, refer to API RP14Cc
b. A good way to analyze the required system design pressure level for the process equipment is to draw the pressure level boundaries in the equipment process flow diagram. In this way, each device (vessel, flange, pipeline or accessory) can be checked to determine whether it is either designed to withstand the highest pressure or protected by a pressure relief device. 1.7 Consideration of corrosion
a) Overview:
Detailed anti-corrosion practices for platform piping systems are not within the scope of this recommended practice. These practices are generally developed by anti-corrosion experts. However, the design of platform piping systems should adopt and comply with the following anti-corrosion practices. Some suggestions on anti-corrosion materials and corrosion mitigation are given in the corresponding chapters of this recommended practice.
: The corrosiveness of the processed fluid may change over time, and the possibility of changing conditions should be considered during the design stage. b. Weight loss corrosion(4) Title 33, Subchapter N, Artficia. Islands and Fixed Structures on the Outer Continental Shelf, Part 140th through 146. (5) Title 33, Part 153, Control of Pollution by Oil and Hazardous Substances, Discharge Removal （6）Title 40, Part 110, Discharge of Oil. （7）Title 40, Part 112, Cil Pollution Prevention. （8）Title 49, Part 192, Minimum Federal Safety Standards for Natural and Other Gas by Pipeline: Mirirmurn Federal Safety Standards for Natural and Other Gas by Pipeline Standards.
(9) Title: 49, Part 195, Transportation of Liquids by Pipeline.
b) Environmental Protection Agency: Document AP-26, Workbook on Atmospheric Dispersion Estinates.
c) Regional Outer (Ontincnlal Shelf) Orders Promulgated under the Code of Federal Regulations, Title 3, Part 25n, Oil and Gas and Sulphur Operations in the Outer Continerual Shelf.
d) Regulations of state, municipal, and other local regulatory agencies also apply. 1.6 Classification of systems by pressure levels Usually, the pressure of the gas stream is gradually reduced after it leaves the wellhead. After the pressure is reduced, the process equipment with lower pressure levels can be used. Figure 1.1 is a typical example. a) A rule for the design of pressure devices is that any pressure-bearing component should be designed to withstand the highest pressure acting on it under any condition, or it should be protected by a pressure relief device. In this case, the pressure relief device is a safety relief valve or a safety disk: Generally speaking, when determining the need for a pressure relief device, the use of high-pressure shut-off valves, non-return valves, control valves or other similar devices to prevent overpressure of the process equipment should not be considered. For the recommended safety devices required for the process equipment, refer to API RP14Cc
b. A good way to analyze the required system design pressure level for the process equipment is to draw the pressure level boundaries in the equipment process flow diagram. In this way, each device (vessel, flange, pipeline or accessory) can be checked to determine whether it is either designed to withstand the highest pressure or protected by a pressure relief device. 1.7 Consideration of corrosion
a) Overview:
Detailed anti-corrosion practices for platform piping systems are not within the scope of this recommended practice. These practices are generally developed by anti-corrosion experts. However, the design of platform piping systems should adopt and comply with the following anti-corrosion practices. Some suggestions on anti-corrosion materials and corrosion mitigation are given in the corresponding chapters of this recommended practice.
: The corrosiveness of the processed fluid may change over time, and the possibility of changing conditions should be considered during the design stage. b. Weight loss corrosion1 is a typical example. a) A rule for the design of pressure devices is that any pressure-bearing component should be designed to withstand the highest pressure acting on it under any condition or be protected by a pressure relief device. In this case, the pressure relief device is a safety relief valve or a rupture disc: Generally speaking, when determining the need for a pressure relief device, the use of high-claw shut-off valves, non-return check valves, control valves or other similar devices to prevent overpressure in the process equipment should not be considered. For recommended practices for safety devices required for process equipment, see API RP14Cc
b. A good way to analyze the required system design pressure level for a process equipment is to draw the pressure level boundaries in the equipment process flow diagram. In this way, each device (vessel, flange, pipeline or accessory) can be checked to determine whether it is either designed to withstand the highest pressure or protected by a pressure relief device. 1.7 Corrosion Considerations
a) General:
Detailed corrosion protection practices for platform piping systems are beyond the scope of this recommended practice. Such practices are generally developed by corrosion experts. However, the design of the platform piping system should adopt and comply with the following anti-corrosion practices. Some suggestions on anti-corrosion materials and corrosion mitigation are given in the corresponding chapters of this recommended practice. The corrosiveness of the process fluid may change over time, and the possibility of changing conditions should be considered during the design stage. b. Weight loss corrosion1 is a typical example. a) A rule for the design of pressure devices is that any pressure-bearing component should be designed to withstand the highest pressure acting on it under any condition or be protected by a pressure relief device. In this case, the pressure relief device is a safety relief valve or a rupture disc: Generally speaking, when determining the need for a pressure relief device, the use of high-claw shut-off valves, non-return check valves, control valves or other similar devices to prevent overpressure in the process equipment should not be considered. For recommended practices for safety devices required for process equipment, see API RP14Cc
b. A good way to analyze the required system design pressure level for a process equipment is to draw the pressure level boundaries in the equipment process flow diagram. In this way, each device (vessel, flange, pipeline or accessory) can be checked to determine whether it is either designed to withstand the highest pressure or protected by a pressure relief device. 1.7 Corrosion Considerations
a) General:
Detailed corrosion protection practices for platform piping systems are beyond the scope of this recommended practice. Such practices are generally developed by corrosion experts. However, the design of the platform piping system should adopt and comply with the following anti-corrosion practices. Some suggestions on anti-corrosion materials and corrosion mitigation are given in the corresponding chapters of this recommended practice. The corrosiveness of the process fluid may change over time, and the possibility of changing conditions should be considered during the design stage. b. Weight loss corrosion
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