Nrf-032-Pemex-2012 - Piping Systems in Industrial Plants

NRF-032-PEMEX-2012 August 14, 2012

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STANDARDS COMMITTEE OF PETROLEOS MEXICANOS AND SUB SIDIARIES PEME PEMEX X REFI REFINAC NACII N TECHNICAL TECHNICAL STANDARDS SUBCOMMI SUB COMMITTEE TTEE

PIPING PIPING SYSTEMS SYSTEMS IN INDUSTRIAL INDUSTRIAL PLANTS PL ANTS DESIGN DESIGN AND MATERIAL MA TERIAL SPECIFICATIONS SPECIFICATIONS (This standard cancels and replaces NRF-032-PEMEX-2005 published on March 18, 2006, Specifications P.2.0371.01, P.2.0370.01, K-101 and GPEI-IT-2001; GNT -SNP-T001-2003, GNT-SNP-T002-2003, GNTSNP-T003-2003 and GNT-SNP-T004-2004)

Standards Committee Petróleos Mexicanos and Subsidiaries

PIPING SYSTEMS IN INDUSTRIAL INDUSTRIAL PL ANTS DESIGN DESIGN AND MATERIAL SPECIFICATIONS

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This Reference Standard was appro ved by the Standards Comm ittee of Petróleos Mexicanos and Subsi diaries at Regular Meeting Meeting 87 held on May 24, 2012. 2012.



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This Reference Standard was appro ved by the Standards Comm ittee of Petróleos Mexicanos and Subsi diaries at Regular Meeting Meeting 87 held on May 24, 2012. 2012.



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TABL E OF CONTENTS CONTENTS CHAPTER

PAGE

0.

INTRODUCTION INTRODUCTION ................................................................................................................ 4

1.

OBJECTIVE ....................................................................................................................... 5

2.

SCOPE ............................................................................................................................... 5

3.

FIELD OF APPLICATION .................................................................................................. 6

4.

UPDATING ......................................................................................................................... 6

5.

REFERENCES REFERENCES ................................................................................................................... 6

6.

DEFINITIONS ....................................................................................................................10

7.

SYMBOLS AND ABBREVIATIONS ..................................................................................13

8.

DEVELOPMENT................................................................................................................14 DEVELOPMENT................................................................................................................14 8.1

Servic Serv ice e requi req uirem rement entss ...............................................................................................14

8.1.1

Mechanical design of piping ................................................................................................ 14

8.1.2

Design of piping pipin g arrangements arrangem ents ................ .................. .................. .................. .................. ... 33

8.1.3

Piping flexibility and supports....................... ................................ .................. .................. .................. .................. .................. .................. ................. ........56

8.1.4

Service Index and Piping Material Specifications (PMS) .......... ................... .................. .................. .................. ............... ...... 63

8.2

Inform Info rmatio ation n to be provi pr ovi ded by PEMEX PEMEX ........... ................. ............ ............ ............. ............. ............ ............ ............ ............ ........65 ..65

8.3

Information to be provided by the Contractor ........................................................65

8.4

Acc eptanc ept ance e crit cr it eria eri a ...................................................................................................68

9.

RESPONSIBIL RESPONSIBILITIES ITIES..........................................................................................................70

10.

ADAPTATION ADAPTA TION TO MEXICAN MEXICAN OR INTERNATIONAL STANDARDS..............................71 STAND ARDS..............................71

11.

BIBLIOGRAPHY BIB LIOGRAPHY ............................................................................................................72

12.

ANNEXES ......................................................................................................................80

12.1 Annex Ann ex 1. Forms For ms ........................................................................................................80 12.2 Annex 2. Index of offs of fshor hor e Piping Pipi ng Materi Materi al Specif icatio ic ations ns (PMS) (PMS) ............. ................... ............ ......84 84 12.3 Annex Ann ex 3. Index In dex of onsh on shor ore e Pipin Pip ing g Materi Mat erial al Specif Spec ific icati ation onss (PMS) .........................89 12.4 Annex Ann ex 4. Requi rem ents to be met m et by b y an " or equi valent val ent"" docu do cumen mentt .................. 101


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INTRODUCTION

Among the main activities carried out at Petróleos Mexicanos and Subsidiaries are oil and gas extraction, collection, primary processing, refining, basic petrochemical production, storage, metering, distribution, repumping and transportation, as well as the design, construction, commissioning, operation and maintenance of the facilities and procurement of the materials and equipment needed to efficiently and effectively accomplish the company's objectives. Operating conditions such as pressure, temperature and environmental effects, among others, have a direct impact on processes for handling fluids such as crude oil, gas, intermediate and finished petroleum products and gas, as well as cryogenic fluids, fluidized solids (catalysts), vents and utilities such as steam, air, water and fuel gas, among others, calling for stringent design and material specifications for the selection of piping, valves, connections and fittings for use in the piping systems at the onshore and offshore industrial plants of Petróleos Mexicanos and Subsidiaries. With the aim of unifying criteria, taking advantage of diverse experiences and combining the results of research in domestic and international standardization, Petróleos Mexicanos and Subsidiaries has issued this technical document to be used in the design and material specification of piping systems in industrial plants. This regulatory document was prepared in observance of and compliance with: Federal Standards and Measures Act and Regulations Petróleos Mexicanos Act and Regulations Public Works and Related Services Act and Regulations Government Procurement, Leases and Services Act and Regulations General Ecological Equilibrium and Environmental Protection Act and Regulations Regulatory Act for Article 17 of the Constitution in the Oil Industry and Regulations Administrative contracting provisions for procurement, leases, works and services in the substantive production activities of Petróleos Mexicanos and Subsidiaries. Supply Policies, Bidding Terms of Reference and General Guidelines in Procurement, Leases and Services for Petróleos Mexicanos, Subsidiaries and Affiliates. Guide for Issuing Reference Standards (CNPMOS-001 Rev. 1, S eptember 30, 2004). The following took part in the preparation of this document: Petróleos Mexicanos: PEMEX-Exploración y Producción PEMEX-Refinación PEMEX-Gas y Petroquímica Básica PEMEX-Petroquímica External participants: Mexican Petroleum Institute Alpha Solutions S.A. de C.V. Cameron Valves & Measurement CPI, Ingeniería y Administración de Proyectos, S.A. de C.V. Engineering de México, S. de R.L. de C.V. Equipos y Servicios VICA, S.A. de C.V.



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George Fischer Piping Systems Grupo Norgam de México, S.A. de C.V. ICA Fluor Daniel, S. de R.L. de C.V. Innovations Performance Pipe TLM Troquelados y Laminados de Monterrey, S.A. de C.V. Tyco Flow Control UPC Interpipe, Inc. Vacoisa International, S.A. de C.V. Victaulic Viega LLC VTC Servicios S. de R.L.

1.

OBJECTIVE

To establish the technical and documentation requirements that must be met in the engineering and material specifications for piping at the industrial plants and offshore facilities of Petróleos Mexicanos and Subsidiaries.

2.

SCOPE

This reference standard establishes the minimum requirements applicable to the design engineering and material specifications for piping used in the processes involved at the onshore and offshore industrial facilities of the work centers of Petróleos Mexicanos and Subsidiaries. It establishes the technical specifications for piping materials, connections and fittings used in processes that include crude oil and gas as raw materials, intermediate and finished products from petroleum and gas processing, as well as cryogenic fluids, fluidized solids (catalysts), vents and utilities such as steam, air, water and fuel gas, among others. This standard does not cover:

a) b) c) d) e) f) g) h)

Piping for radioactive services. Piping for power or force covered by ASME B31.1:2010 or equivalent. See 8.1.4.1.5 for particular cases. Piping covered by ASME B31.4:2009 or ASME B31.8:2010 or equivalents (onshore surface or buried pipelines, marine or undersea pipelines). Piping for heat transfer Piping in ground or maritime transportation vehicles, such as tank trucks and vessels, among others. Tie-in piping between industrial and maritime facilities (ships, wharves, among others) covered by other standards. Piping for drilling Plumbing systems

This standard cancels and replaces NRF-032-PEMEX-2005 published on March 18, 2006, Specifications P.2.0371.01, P.2.0370.01, K-101 and GPEI-IT-2001; GNT -SNP-T001-2003, GNT-SNP-T002-2003, GNTSNP-T003-2003 and GNT-SNP-T004-2004.


3.


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FIELD OF APPLICATION

This reference standard is generally applicable and mandatory in the procurement, leasing or contracting of services covered hereunder at the work centers of Petróleos Mexicanos and Subsidiaries. Therefore, it must be included in public bidding procedures, invitations to at least three parties (restricted invitation in the Petróleos Mexicanos Act) and direct awards involving contracts for purchases, services and public works or related services, as part of the requirements to be met by the vendor, contractor or bidder. In repairs, modifications or expansions of existing industrial facilities, the requirements established in this reference standard must be met in the following cases: − − −

If the original design's Piping Material Specifications are not available. If the original design's Piping Material Specifications are obsolete. If repairs, modifications or expansions of existing facilities change the original design's operating conditions.

When any parts of existing facilities are substituted or replaced and the requirements for the original design are retained, such parts shall be considered as within specification.

4.

UPDATING

This reference standard must be reviewed and, if appropriate, modified at least every 5 years or earlier if the suggested and recommended changes so warrant. Proposed and suggested changes should be submitted on form CNPMOS-001-A01 of the Guide for Issuing Reference Standards CNPMOS-001 Rev. 1 dated September 20, 2004, and sent to: Standards Committee of Petróleos Mexicanos and Subsidiaries Avenida Marina Nacional, No. 329, 35th Floor, Executive Tower Colonia Petróleos Mexicanos, Postal Code 11311, Mexico, Federal District Direct phone: 19-44-92-40; Switchboard: 19-44-25-00, Ext. 5-47-81 E-mail: [email protected]

5.

REFERENCES

5.1

NOM-008-SCFI-2002. General system of units of m easure.

5.2

NOM-011-STPS-2001. Safety and health conditions at work centers where noise is generated.

5.3

NOM-018-STPS-2000. System for identifying and reporting hazards and risks arising from hazardous chemical substances at work centers. 5.4

NOM-093-SCFI-1994. Steel and bronze spring-loaded and pilot-operated pressure relief valves (safety, safety-relief and relief valves). 5.5

NMX-CC-9001-IMNC-2008. Quality management systems - Requirements (ISO 9001:2008 with

ISO 9001:2008/Cor 1:2009).

5.6

NMX-CC-9004-IMNC-2009. Managing for the sustained success of an organization - a quality management approach ( ISO 9004:2009).



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5.7 NMX-CC-10005-IMNC-2006. Quality management systems - guidelines for quality plans (ISO 10005-2005). 5.8

NMX-E-018-SCFI-2002.

Plastics industry – high-density polyethylene (HDPE) pipe for

pressurized water - Specifications.

5.9

NRF-009-PEMEX-2004. Identification of products transported by piping or contained in storage

tanks.

5.10

NRF-015-PEMEX-2008. Protection of inflammable or combustible product storage areas and

tanks.

5.11

NRF-016-PEMEX-2010. Design of firefighting systems.

5.12

NRF-026-PEMEX-2008. Anticorrosion coating protection for buried and/or submerged pipe.

5.13

NRF-027-PEMEX-2009.

Alloy steel and stainless steel studs and bolts for high and low

temperature service.

5.14

NRF-028-PEMEX-2010. Design and construction of pressure vessels.

5.15

NRF-031-PEMEX-2011. Venting and flaring systems in facilities.

5.16

NRF-034-PEMEX-2011. Thermal insulation for high temperatures in equipment, vessels and

surface piping.

5.17

NRF-035-PEMEX-2005. Piping systems in industrial plants - installation and testing.

5.18

NRF-049-PEMEX-2009. Inspection and supervision of movable property leases and services.

5.19

NRF-053-PEMEX-2006. Coating-based anticorrosion protection systems for surface facilities.

5.20

NRF-107-PEMEX-2010. Intelligent 2D and 3D electronic models for facilities.

5.21

NRF-127-PEMEX-2007. Seawater-based firefighting s ystems at fixed offshore facilities.

5.22

NRF-139-PEMEX-2012. Piping supports - Design.

5.23

NRF-140-PEMEX-2011. Drainage systems.

5.24

NRF-142-PEMEX-2011. Plug valves.

5.25

NRF-156-PEMEX-2008. Joints and gaskets.

5.26

NRF-158-PEMEX-2012. Metal expansion joints.

5.27

NRF-171-PEMEX-2007. Rubber expansion joints.

5.28

NRF-204-PEMEX-2102. Emergency shutoff valves (remotely actuated isolation valves)

5.29

NRF-211-PEMEX-2008. Gate and ball valves in oil and gas transportation lines.



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5.30

NRF-248-PEMEX-2010. Electrical trace heating systems - Design.

5.31

NRF-268-PEMEX-2010. Articulated platforms with electric motors or internal combustion engines.

5.32

NRF-271-PEMEX-2011. Composition of the project book for delivery of works and services.

5.33

NRF-281-PEMEX-2012. Anticorrosion protection based on hot-dip galvanizing.

5.34

ISO 3183:2007. Petroleum and natural gas industries - Steel pipe for pipeline transportation

systems.

5.35

ISO 5208:2008. Industrial valves - Pressure testing metal valves.

5.36

ISO 7005-1:2011. Pipe flanges Part 1: Steel flanges for industrial and general service piping

systems.

5.37

ISO 10434:2004. Bolted bonnet steel gate valves for the petroleum, petrochemical and allied

industries (ISO 10434:1998 is parallel to API Std 600:2001).

5.38

ISO/TS 10465-1:2007

5.39

ISO 10497:2010. Testing of valves - Fire type-testing requirements.

Underground installation of flexible glass-reinforced pipe based on unsaturated polyester resin (GRP-UP) - Part 1. Installation procedures.

5.40

ISO 13703:2002 with ISO 13703:2002 Cor 1:2002. Petroleum and natural gas industries. Design and installation of piping s ystems on offshore production platforms. 5.41

ISO 14313:2007 with ISO 14313 Cor 1:2009. Petroleum and natural gas industries - Pipeline

transportation systems - Pipeline valves. This international standard is the result of harmonizing the requirements in ISO 14313:1999 and API Spec 6D-2002).

5.42

ISO 14692-1:2002 Petroleum and natural gas industries - Glass-reinforced plastic (GRP) piping -

Part 1: Vocabulary, symbols, applications and materials.

5.43

ISO 14692-2:2002 with ISO 14692-2:2002/Cor 1:2005 Petroleum and natural gas industries Glass-reinforced-plastic (GRP) piping - Part 2: Qualification and manufacture. 5.44

ISO 14692-3:2002. Petroleum and natural gas industries. Glass-reinforced-plastic (GRP) piping -

Part 3: System design.

5.45

ISO 14692-4:2002 wi th ISO 14692-4:2002/Cor 1:2006 Petroleum and natural gas industries -

Glass-reinforced-plastic (GRP) piping - Part 4: Fabrication, installation and operation.

5.46

ISO 15156-1:2009. Petroleum and natural gas industries. Materials for use in H 2 S-containing environments in oil and gas production - Part 1: General principles for selecting cracking-resistant materials. 5.47

ISO 15156-2:2009. Petroleum and natural gas industries. Materials for use in H 2 S-containing environments in oil and gas production - Part 2: Cracking-resistant carbon and low-alloy steels and the use of cast irons. [In 2003, the publication of the three parts of ISO 15156 and NACE MR0175/ISO 1516 were completed. These technically identical documents used the [same] sources to maintain requirements and



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recommendations for material qualification and selection in environments containing wet H 2 S in petroleum and gas production systems. They are supplemented by NACE TM0177 and NACE TM0284).

5.48

ISO 15156-3:2009. Petroleum and natural gas industries. Materials for use in H 2 S-containing environments in oil and gas production - Part 3: Cracking-resistant CRA’s (corrosion-resistant alloys) and other alloys. 5.49

ISO 15649:2001. Petroleum and natural gas industries - Piping.

5.50

ISO 15761:2002. Steel gate, globe and check valves for sizes DN 100 and smaller for the petroleum and natural gas industries. (Parallel to the specifications found in API Std 602). 5.51

ISO 15848-1:2006. Industrial valves - Measurement, test and qualification procedures for fugitive

emissions - Part 1: Classification system and qualification procedures for type testing of valves.


6.


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DEFINITIONS

For the purposes of this standard, the following definitions apply:

6.1

Support: Element on which the piping rests and is fixed.

6.2

Zero leaks (in valve seats): No visible leak (dripping or bubbling) for the duration of the test in

accordance with ISO 5208:2008.

6.3

Piping circui ts:

6.4

Class: Non-dimensional designation for classifying piping components that relates a pressure-

Set of piping and equipment that handle a substance with the same composition, in which operating conditions ma y vary in its different parts. temperature range based on the mechanical properties of the materials, as well as the necessary dimensions for coupling between piping components; in the American system.

6.5

Pipeline. The components through which hydrocarbons and their derivatives are collected and

transported between stations and/or facilities, including pipes, piping components, pig traps, fittings, isolation and sectioning valves.

6.6

Piping compon ents: Any element that forms or assembles (by welding or another type of connection) a piping system, piping circuit or piping. 6.7

Constructability: Technique as a system to achieve an optimum integration of knowledge and construction experience in planning, engineering and construction operations; aimed at dealing with the particularities of the project and the restrictions of the surrounding area for the purpose of reaching the project's objectives. 6.8

Service Specifi catio n (SS): Document that describes, indicates and establishes the minimum characteristics which the piping must have, as well as the user's particular requirements, service life, design and operating conditions, environment, material safety data sheets, physical and chemical properties of the fluids (substances), safety, operating flexibility and applicable rules and regulations, in conformance with this reference standard. 6.9

Pipin g Material Specifi cation (PMS): Document establishing the group of piping components,

their materials, Class, characteristics and construction requirements for handling one or more services within a given operating range (pressure-temperature).

6.10

Equivalent: Per Annex 12.4 of this reference standard.

6.11

Water hamm er: Sudden and unexpected pressure increase in the piping due to a change in the dynamic state of the fluid, like the pressure increase caused by the abrupt closing of a valve, among other things. 6.12

Process data sheets: Document containing the basic information on equipment or vessels or

instruments. This information may consist of: dimensions, form, type, connection ends, service, operating conditions, material specifications, and components, among others.

6.13

Basic engin eering: State of a project that consists of defining the layouts, designs and general

specifications, material and energy balances, piping and equipment diagrams, among others, which are prepared on the basis of design concepts and technology selected during the conceptual engineering phase. The specifications are prepared for quoting equipment and defining the service and construction or fabrication requirements.


6.14


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Detail Engineering: Final design stage of a project, which includes the final detail drawings for

construction and/or fabrication prepared on the basis of the basic engineering and extended basic engineering if available. Detail engineering includes updated specifications for equipment procurement and complete definition of the construction requirements and suppl ies.

6.15

Respons ibl e engin eer: Engineer with technical and legal authority and a professional I.D. issued by the Mexican Government or its international equivalent and with at least five years of proven experience in the engineering of piping of the same magnitude and importance, who signs, initials and endorses the documents with his professional I.D. 6.16

Pipin g Isometri c: Drawing with the orthogonal representation of a piping design showing its

route, components, dimensions, location, characteristics and construction requirements.

6.17

Nominal: A numerical identification for dimensions, capacities, stresses, Classes and other characteristics that are used as a property, not an exa ct measurement. 6.18

Series (of flanges or "flange series"): Classification system for flange design, resulting in Class

series and PN series in accordance with ISO 7005:2011.

6.19

Cryogeni c servi ce: Service at temperatures below -196 °C (-320°F).

6.20

Low -temperature servic e: Service at temperatures between -28 °C (-20°F) and -196°C

(-320°F).

6.21

Saddle: Support for adjusting piping elevation and transferring the actions to the piping support;

formed by a 120 ° to 180° segment of a cylinder or pipe with structural fastening elements.

6.22

Piping system: Interconnected piping subject to the same design conditions.

6.23

Piping support : Structure designed to support the piping, such as piping racks, surface piping supports and support blocks, among others. 6.24

Hazardous substances (or hazardous chemical substances): Substances whose physical

and/or chemical properties may entail health, inflammability, reactivity or special risks when being handled, transported, stored or processed, and can affect the health of persons exposed to them or cause physical damage to facilities. They are classified by their hazard levels in accordance with NOM018-STPS-2000.

6.25

Non-hazardous subs tances: Chemical substances that are not inflammable, toxic or reactive

and do not cause damage to human tissue or the environment; substances with a design pressure lower 2 than 686 kPa (7 kg/cm ) and/or a design temperature of -29 °C to 50°C (-20°F to 122°F).

6.26

Licensor: Contractor owning the technology or the licensed rights to use the technology.

6.27

Trim: Name for the valve internals, which in include the description and characteristics of the

material specifications for: a) b) c) d) e) f)

Stem Surface of the seat for gate or disc Surface of the seat for the body (rings) Stem guide bushings Bolt or pin joining the stem with the gate, if applicable Other elements specified in the Piping Material Specification



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6.28 Piping . Assembly of pipes and piping components used to transport, distribute, mix, separate, discharge, meter, control or deter the flows of a fluid or substance (piping system, piping circuits and/or piping, as applicable).

6.29 Piping: Piping system, piping circuit and/or piping. 6.30 Pipe: Leak-tight hollow cylinder used to transport a fluid or move a pressurized fluid.


7.


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SYMBOLS AND ABBREVIATIONS

CS AWWA BSI W/S CGA DN EEMUA W/T Ej PMS SS FM FF Gr. RF LFMN MSS N/A NDT NPT NPS NRF NSF HDPE PFI PTFE PSV Stress Rel. RF RPTFE RT RJ RTJ RTRP Rx N/S UL UT

Carbon Steel American Water Works Association British Standard Institute Seamed Compressed Gas Association Nominal Diameter Engineering Equipment and Materials Users Association Pipe wall thickness Joint efficiency Piping Material Specification Service Specification Factory Mutual Insurance Company Flat face Material grade Raised face Federal Standards and Measures Act and Regulations (for its initials in Spanish) Manufacturers Standardization Society of the Valve and Fittings Industry Not applicable Non-destructive tests National Pipe Thread Nominal Pipe Size Reference Standard National Sanitation Foundation High-density polyethylene Pipe Fabrication Institute Polytetrafluoroethylene (Teflon®). Safety, safety-relief, relief, pressure relief valves. Stress relief Raised face Reinforced polytetrafluoroethylene Radiographic test Ring joint Ring-type joint gasket Reinforced thermosetting resin pipe X-rays Seamless Underwriters Laboratories Inc. Ultrasound test

For the purposes of this reference standard with regard to symbols and units of measure, see NOM-008SCFI-2002.


8.

DEVELOPMENT

8.1

Service requi rements


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Piping design and material specifications at onshore and offshore industrial facilities must comply with this reference standard. Cases not covered by this standard must comply with ISO 15649:2001 and ISO 13703:2002, respectively, and are subject to the requirements of ASME B 31:3:2010. The figures in this reference standard are schematic and should not be interpreted as construction or design drawings.

8.1.1

Mechanical design of pipi ng

The mechanical design of piping must be prepared on the basis of design and service conditions and comply with ASME B31:3:2010 Chapter II, including but not limited to the following:

a) b) c) d) e) f) g) h) i) j) k) l)

Maximum and minimum temperatures, both for the process and the environment. Maximum and minimum pressures of the piping circuit. Physical and chemical properties of the substances and their hazard levels. Compatibility between the materials of the piping components, the contained substance and the environment. Compatibility between the materials of the piping components and their mechanical strength. Constructability and operation and maintenance facilities. Environmental effects that impact the piping. Effects resulting from the service, installation, supports and geographical location that impact the piping. Required minimum service life (corrosion and erosion) Permissible stresses and other stress limits Variations in pressure/temperature conditions Tolerances and mechanical strength.

8.1.1.1 Piping dimensi ons and requirements 8.1.1.1.1 General r equir ements For the pressure design of the piping, ASME B31.3:2010 Paragraphs 303 and 304 must be observed in accordance with the requirements of this reference standard. The minimum nominal diameter for piping in all services must be DN 20 (NPS ¾); in exceptional cases, nipples may be DN 15 (NPS ½) in arrangements for in struments.

8.1.1.1.2 Carbon, intermediate- and low -alloy steel pip ing 8.1.1.1.2.1 Carbon, intermediate- and low-alloy steels and other alloys, with the exception of stainless steels, must comply with the dimensions and r equirements of ASME B36.10M:2004 or equivalent.

8.1.1.1.2.2 DN 20 to 50 (NPS ¾ to 2) carbon, intermediate- and low-alloy steel piping must be at least Schedule 80, even when calculations give smaller thicknesses.



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8.1.1.1.2.3 DN 80 (NPS 3) to DN 600 (NPD 24) carbon steel piping must be at least standard schedule (STD), even when calculations give smaller thicknesses.

8.1.1.1.2.4 DN 65 (NPS 2½) piping must only be specified for firefighting systems. systems. DN 125 (NPS 5) piping only applies to drilling packages and should not be specified in other cases.

8.1.1. 8.1.1.1.3 1.3 Stainless steel pip ing 8.1.1.1.3.1

Stainless steel piping must comply with the dimensions and requirements of ASME B36.19M:2004 or equivalent. When dimensions not covered by ASME B36.19M:2004 or equivalent are necessary, the requirements of ASME B36.10M:2004 or equivalent must be met.

8.1.1.1.3.2 For DN 20 to to 40 (NPS ¾ to 1½) stainless stainless steel piping, the minimum schedule must be 80S. For DN 50 (NPS 2), the minimum schedule must be 40S. Even when calculations give smaller thicknesses, they should not be specified.

8.1.1.1.3.3 For DN 80 (NPS 3) and larger stainless steel steel piping, the minimum schedule must be 10S. Even when calculations give smaller thicknesses, they should not be specified.

8.1.1. 8.1.1.1.4 1.4 Non-ferrou s metal pip ing 8.1.1.1.4.1 Pipe dimensions must comply with the dimensions and requirements of ASME ASME B36.19M:2004 or ASME B36.10M:2004 or equivalents; for pipes fabricated from plate, the minimum thickness must be expressed according to the ASTM specification for the plate given in the relevant Piping Material Specification.

8.1. 8.1.1. 1.2 2 Seamless Seamless and longit udinally s eamed eamed piping 8.1.1.2.1 Pipes may be seamless or seamed . The Piping Material Material Specifications forming part of this standard indicate when seamed or seamless pipe must be used.

8.1.1.2.2 Seamed piping for services with hazardous substances must have a joint efficiency of 1. For non-hazardous substances, the minimum joint efficiency must be 0.85.

8.1.1.2.3 Piping for severe cyclical service must be seamless up to DN 600 (NPS 24) and seamed for larger DN’s in compliance with ASME B31.3:201 Paragraph 305.2.3.

8.1. 8.1.1. 1.3 3 Unions between piping compon ents 8.1.1.3.1 In corrosive fluids, piping piping and piping components with with beveled ends for butt welding must be used in all diameters. 8.1.1.3.2 Socket weld unions are not permissible for piping in any of the following services: a) b) c)

Risk of or substances that induce corrosion, crevice corrosion, or erosion. Severe mechanical vibration Hydrogen

8.1.1.3.3 The minimum separation between contiguous circumferential welds in piping arrangements must be as follows: For onshore facilities:


a) b) c) d)


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90 mm (3.5 in) for ND 50 (NPS 2) and smaller 1.5 times the DN for DN 80 to 100 (NPS 3 to 4) 1.0 times the DN for DN 150 to 500 (NPS 6 to 20) 0.5 times the DN for DN 600 (NPS 24) and larger

For offshore facilities:

a) b) c)

90 mm (3.5 in) for ND 50 (NPS 2) and smaller 1.5 times the DN for DN 80 to 100 (NPS 3 to 4) 1.0 times the DN for DN 150 (NPS 6) and larger

8.1.1.3.4 The separation between pipe-pipe circumferential circumferential seams in straight piping must be no less than 6 m for non-ferrous metal pipe or 12 m for carbon, intermediate- and low-alloy steel pipe. Except in continuous straight piping runs where an adjustment spool is specified by design, only one should be used.

8.1.1.3.5 Threaded connections should only be specified in piping for the following services: a) b) c) d) e)

Non-hazardous substances Non-erosive substances Substances that do not induce corrosion or crevice corrosion Operating pressure below 2 MPa (300 psi), and Drains or vents downstream from shutoff valves with nipples and threaded plugs.

8.1.1.3.6 Piping with a grooved connection system must comply with ASME B31.3:2010 and AWWA C606-2011 or equivalent. It should only be specified in offshore facilities facilities or temporary onshore facilities for service with non-hazardous, non-polluting substances where, in the event of failure, it does not put continuous operation of the facilities at risk, and at the specific request of PEMEX in the Service Specification and with the respective Piping Material Specification. It should not be specified for permanent industrial refining, petrochemical or gas-processing facilities.

8.1. 8.1.1. 1.4 4 Radiographi Radiographi c testing in welded joints 8.1.1.4.1 Welded circumferential joints in piping must be inspected with radiographic radiographic testing (X-ray or or gamma-ray, as applicable) by design in compliance with ASME B31.3:2010, and with at least the following percentage per service, which applies when at least one of the following conditions is met:

a)

100 100 percent for service with: - Hazardous substances with level 4 health risk according to NOM-018-STPS-2000 - Piping in severe cyclical conditions as defined in ASME B31.3:2010 B31.3:2010 Paragraph 302.3.5 - Design temperatures 25 °C or 50°F below the temperature limit established for the material specification (Numbers P4 and P5) according to ASME B31.3:2001, Table A-1 - Hydrogen service - Class 1500 or larger

b)

50 percent for service with: - Hazardous substances with level 3 health risks according to NOM-018-STPS-2000. - Class 900.

c)

33 percent for service with: - Hazardous substances with level 2 health risk according to NOM-018-STPS-2000. - Class 600.


d)


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20 percent for service with: - Hazardous substances with level 1 health risk according to NOM-0180-STPS-2000. - Class 300.

e)

10 percent for service with: - Hazardous substances with level 0 health health risk according to NOM-018-STPS-200 in Class 150

f)

5 percent for services with: - Non-hazardous substances substances in Class 150.

Note 1: When a substance is not classified in NOM-018-STPS-2000, the safety datasheet should be consulted, and in the absence thereof, a risk analysis should be performed. Note 2: For inspection of of fillet welds that that cannot be inspected with radiographic testing (X-ray or gammaray), see NRF-035-PEMEX-2005.

8.1.1.4.2

The percentage of radiographic testing for piping in service with hazardous substances substances with any degree of inflammability, reactivity or special risk must be at least that indicated in the preceding subparagraphs by Class.

8.1.1.4.3 In the case of piping in service with substances to which two or more radiographic testing percentages apply, the higher percentage must be used.

8.1.1.4.4 The specified percentage of welds or joints to be tested applies applies for butt-welds or butt-welded butt-welded or socket-weld joints made by each of the welders or welding machine operators using the same welding procedure (WPS). These connections must be X-rayed over the en tire circumference.

8.1.1.4.5 When the percentage results in a fraction of a joint, the results should be rounded up to the next highest number of joints.

8.1.1.4.6 For the detection of defects defects in the welds selected within the the radiographic testing percentages described in this reference standard, the number of joints to be inspected must be increased based on the requirements of ASME B31.3:2010 Paragraph 341.3.4.

8.1.1.4.7 Circumferential welds in firefighting system system piping must only be inspected by radiography. radiography. 8.1.1.5 Heat Treatment 8.1.1.5.1 When piping system pipes and components require heat treatment in addition to the standard treatment for manufacture of the material according to the requirement of the service to be handled, such treatment must be indicated in the respective Piping Material Specification.

8.1.1.5.2 Piping fabricated in the field or shop must be heat-treated and/or stress-relieved as established in ASME B31:3.2010 for the respective material, thickness and fabrication process. This requirement must be indicated as a supplement in the respective Piping Material Specification.

8.1.1.5.3 Piping that requires heat treatment and/or stress relief due to the service must comply with the Piping Material Specifications of of this reference standard. The respective requirements indicated indicated in the following documents must be met for services not included in the Piping Material Specifications:

a) b)

NACE SP0403:2008 or equivalent for caustic service. ISO 1516:2009 for sour service in oil and gas, as well as for natural gas treatment plants.


c) d) e) f) g) h)


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NACE MR0103:2010 or equivalent for hydrosulfuric acid in oil refining and related processing containing H 2 S in gas or dissolved in the aqueous phase, with or without hydrocarbon processes. NACE SP0472:2008 or equivalent and API RP945:2008 or equivalent for amine service. API RP 941:2008 "Nelson Chart" or equivalent for material selection in hydrogen service where any combination of operating conditions plus 30 °C or 54°F in addition to the corresponding temperature must remain under the material's curve. API RP 934-A:2008/934-C:2001 or equivalent for hydrogen service at high temperatures. API RP 751:2007 or equivalent, NACE SP0472:2008 or equivalent and NACE 5A171:2007 or equivalent for hydrofluoric acid (HF) or anh ydrous hydrogen fluoride (AHF) service. NACE RP0170:2004 or equivalent.

8.1.1.6 Corro sion and erosi on tolerance 8.1.1.6.1 Corrosion and erosion tolerance is the additional thickness that must be included for wear due to corrosion and erosion. For carbon or low- and intermediate-alloy steels, it must be equal to or greater than the fluid wear rate for the piping material as given in NACE 37519:1985 or equivalent, supplemented with API RP 581:2008 or equivalent for a service life of 20 years (unless specified otherwise for the project), but no less than the following:

a) b)

1.6 mm (0.0625) for service that generate uniform wear less than 0.076 mm/year (0.003 in/year). 3.2 mm (0.125 in) for service that generate uniform wear between 0.076 mm/year (0.003 in/year) and 0.152 mm/year (0.006 in/year).

8.1.1.6.2 For piping that must handle substances with a wear rate requiring a corrosion tolerance greater than those indicated in 8.1.1.6.1(b), corrosion-resistant materials for uniform wear lower than those given in NACE 37519:1985 or equivalent should be selected when economically feasible.

8.1.1.6.3 For piping made of stainless steel, non-ferrous materials and/or their alloys (nickel, titanium and tantalum, among others) that handles non-corrosive fluids, the corrosion tolerance must be zero.

8.1.1.7 Piping components 8.1.1.7.1 Nipples 8.1.1.7.1.1 The length of nipples for piping with no thermal insulation system must be from 90 mm (3.5 mm) to 100 mm (4 in.); and for piping with a thermal insulation system, 150 mm (6 in.) to 170 mm (6.5 in.).

8.1.1.7.1.2 The permissible minimum diameter is DN 20 (NPS ¾). For instrument connections, it may be ND 15 (NPS ½).

8.1.1.7.1.3 Concentric or eccentric reducing nipples (swage nipples) must be fabricated in accordance with the requirements of MSS SP-95:2006 or equivalent. Reducers (swage nipples) are only permissible when they are a particular requirement of the Piping Material Specification covered b y this standard.

8.1.1.7.1.4 In concentric or eccentric reducing nipples (swage nipples), the permissible smaller diameter is DN 15 to 50 (NPS ½ to 2) and the permissible larger diameter is DN 20 to 80 (NPS ¾ to 3). They must be specified with both ends flat or flat-threaded ends, as applicable. In the case of DN 80 (NPS 3), they must be joined to the piping with bevels and butt welding.

8.1.1.7.2 Threaded connections



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8.1.1.7.2.1 Threaded connections are only permissible for DN 20 to 50 (NPS

to 2), except where

indicated in the Piping Material Specifications of this reference standard.

8.1.1.7.2.2 Threaded connections must be NPT in accordance with ASME B1.20.1:1983 and ASME B16.11:2009 or equivalents.

8.1.1.7.2.3 Threaded connections must be Class 3000 or 6000. The carbon steel pipes to be joined must be schedule 160 for Class 3000 and schedule XXS for Class 6000, in accordance with ASME B16.11:2009, Table 7, or equivalent.

8.1.1.7.2.4 Bull plugs must be solid bar with a hex head or a round head. 8.1.1.7.2.5 Cap plugs and street elbows (female-male thread) must be Class 6000; see Fig. 1. 8.1.1.7.2.6 Plugs with square heads, bushing-type reducers, coupling nuts or hollow plugs should not be specified.

8.1.1.7.2.7 Threaded connections should not be specified for thermowells.

Solid bar bull plug

Street elbow

Cap plug

Fig. 1. Bull pl ug, street elbow and cap plug . 8.1.1.7.2.8 Threaded ends in service with hazardous substances must be sealed with continuous welding and no exposed threads must remain.

8.1.1.7.3 So cket-weld end connecti ons 8.1.7.3.1 Socket-weld end connections must be DN 50 (NPS 2) and smaller and comply with ASME B16:11:2009 or equivalent.

8.1.1.7.3.2

Socket-weld end connections must be Class 3000, 6000 or 9000, except for nipolets in offshore Piping Material Specifications, where they must be at least Class 6000. The carbon, low- and intermediate-alloy steel pipes to be joined with these connections must be at least schedule 80 for Class 3000, schedule 160 for Class 6000. and schedule XXS for class 9000 in accordance with ASME B16.11:2009 Table 7 or equivalent.

8.1.1.7.3.3 Socket-weld end connections for stainless steel and non-ferrous metal piping (titanium, aluminum, nickel and other alloys) must be at least Class 3000 with schedule 40S pipes, even when calculations give smaller thicknesses. For intermediate schedules, the next highest Class and schedule must be specified in accordance with ASME B16.11:2009, Table 7, or equivalent.

8.1.1.7.4 B utt-w eld end connectio ns 8.1.1.7.4.1 Up to DN 1200 (NPS 48), they must comply with ASME B16.9:2007 or equivalent, and for larger diameters up to DN 1500 (NPS 60), with MSS SP-75:2008 or equivalent.



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8.1.1.7.4.2 They must have the same wall thickness or schedule as the pipe to which they are joined. 8.1.1.7.4.3 Elbows must be long radius regardless of their DN (NPS), except in offshore facilities where they may be short radius due to space limitations.

8.1.1.7.4.4

Direction changes must be made with factory connections and not with bent pipe, unless otherwise indicated in the Piping Material Specifications due to the process technology and/or service requirements, in which case ASME B31.3:2010, Para graph 304.2.1, must be observed.

8.1.1.7.4.5 "Improvised" piping connections such as mitered elbows, sectioned reducers, sectioned plugs, pencil point terminations, and welded flat covers made of plate, among others, should not be used for process piping or in service with hazardous substances.

8.1.1.7.4.6 Mitered elbows and "improvised" reducers may only be used in cooling water or utility water service in Class 150 with DN larger than 650 (NPS 26) and must be:

a) b) c)

Long-radius elbows of at least 3 sections with a complete penetration circumferential seam, 100% X-rayed per ASME BN31.3.2010, Paragraph 304.2. Improvised reducers must be rolled, with a complete penetration butt-welded longitudinal seam, 100% X-rayed, and with dimensions per MSS SP-75:2008 or equivalent. Elbows must be fabricated from pipe with the same Piping Material Specification as the piping.

8.1.1.7.4.7 The use of direct pipe-to-pipe branch connections should not be specified except for atmospheric drains and as indicated in 8.1.1.7.4.8.

8.1.1.7.4.8 Tie-ins between new and existing facilities in particular cases where the clearance cannot be made must be implemented with integrally reinforced connections, split tees or branch connections reinforced with casing (made of the same material as the piping), and must comply with the requirements given in API RP 2201:2010 or equivalent. In the case of branch connections with a diameter ratio greater than 2/3 branch/header or Class 300 and up, a split tee must be used.

8.1.1.7.4.9 For tie-ins between new and existing facilities where clearance can be made and a branch is inserted which, by design, requires that such branches be located next to one another, the separation must be as given in the applicable tables of Figures 2 and 3 in Standard PFI-ES-7:2004 or equivalent, and the branches must have the type of connection indicated in the branch tables of the Pipe Material Specifications.

8.1.1.7.4.10 Lateral 45° Y’s (Fig. 2) must be one-piece construction, seamless, with a uniform wall, and should not intersect with angled finishes or cutting edges and must comply with the requirements given in ASME B16.9:0207 or equivalent. No exceptions are permissible, even the exception indicated in Section 5 of said standard.

Lateral 45° Y fitting

Reduced lateral 45° Y fitting

Fig. 2. Y Fitti ngs



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8.1.1.7.5 Integrall y reinfo rced connecti ons 8.1.1.7.5.1 May be Threadolet, Sockolet, Weldolet or equivalent, which must comply with the dimensions and requirements given in MSS SP-97:2010 or equivalent; as well as Latrolet, Nipolet, Elbolet or Nipple Pipet or equivalent, which m ust comply with ASME B31.3:2010, Paragraphs 302.2, 304.3 and 326.5.

8.1.1.7.5.2 Integrally reinforced connections must be specified with branch diameter and header diameter; see Fig. 3.

8.1.1.7.5.3 Beveled ends must comply with ASME B16.25:2007 or equivalent and the union with the header should have a maxim um gap of 1.6 millimeters (0.0625 in.); see Fig. 4. Threaded end (NPT) for branch

Socket-weld end for branch

Beveled end for welding to header “Threadolet”

Beveled end for welding to header “Sockolet”

Beveled-weld end for branch

Beveled-weld end for 45° Y branch

Beveled end for welding to header “Weldolet”

Beveled end for welding to header “Lateral”

Socket-weld end for 45° Y branch

Beveled end for welding to header “Latrolet”

Fig. 3. Integrally reinforc ed connections

Flat end

Beveled end for welding Nipolet or nipple pipet

Integrally reinforced connector

Minimum gap

1/16" maximum gap

Minimum gap

Maximum gap

Specify minimum header diameter allowing the connector to be seated on the i e.

Figure 4. Minimum gap 8.1.1.7.5.4 When the branch is DN 50 (NPS 2) or smaller, the Sockolet and Threadolet fittings must be in accordance with dimensions given in ASME B16.11:2009 or equivalent and limited to DN 50 (NPS 2).

8.1.1.7.5.5 In the Sockolets, a minimum gap of 1.16 millimeters (1/16 in.) must be allowed in the socket. 8.1.1.7.5.6 The threaded ends of the Threadolets must be sealed with welding after the nipple or plug is installed.

8.1.1.7.6 Flanges



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8.1.1.7.6.1 Flanges should not be specified for fabrication from plate, regardless of DN and Class. 8.1.1.7.6.2 Flanges must comply with ISO 7005-1:2001 Class series, with the requirements of ASME B16.5:2009 for DN’s up to 600 (NPS 24), and with the requirements of ASME B16.47:2011 Class Series A for DN 650 to 1500 (NPS 26 to 60).

8.1.1.7.6.3 Flanges larger than DN 1520 (NPS 60) must be calculated according to ASME Section VIII Division 2:2010 or equivalent, and the dimensions must be listed in the piping isometrics. These flanges must be supplied with a mating flange, hardware and gasket, unless otherwise specified in the Service Specification.

8.1.1.7.6.4 Flanges must be the weld neck, socket weld, long neck, lap joint, or slip-on or blind type (see Fig. 5) as specified in the respective Piping Material Specification; with raised face (RF) or ring joint (RJ also known as RTJ) for metal flanges; and flat face (FF) for non-metal or copper-nickel alloy flanges.

SLIP-ON

LAP JOINT

WELDING NECK

LONG WELDING NECK

SOCKET WELD

BLIND



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Pressure tap Seal by welding

Equal bores flange - pipe

Dress weld

Orifice plate

ORIFICE Fig. 5. Types of Flang es 8.1.1.7.6.5

The finish on the flange faces must comply with ASME B.16.5:2009 Paragraph 6.4.5, as applicable for the service and gasket.

8.1.1.7.6.6 Welding neck flanges may be specified in all DN’s and classes. 8.1.1.7.6.7 Welding neck flanges must have the same bore and schedule or thickness as the pipe or piping component to which they are joined.

8.1.1.7.6.8 Socket weld flanges should not be specified for DN’s larger than 50 (NPS 2). 8.1.1.7.6.9 Lap joint flanges may only be specified for piping made of non-ferrous metal materials and up to Class 150.

8.1.1.7.6.10 Taps for thermowells must be made with long neck flanges, at least Class 300. The OD of the thermowell must pass through the ID of the long-neck flange; see Fig. 6

Thermowell

Long-neck flange Pipe wall

Fig. 6. Long-neck flanges for thermowell taps 8.1.1.7.6.11 Blind flanges must be factory forged and may be specified in all DN’s and Classes. Flanges fabricated from plate are not permissible, regardless of the DN and Class.

8.1.1.7.6.12. Reducing flanges must be limited to Class 150 and up to DN 600 (NPS 24). Their particular application is given in the Piping Material Specifications. Reducing flanges fabricated from blind or plate flanges are not acceptable.



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8.1.1.7.6.13 Slip-on flanges may only be specified in Class 150 for service with non-hazardous substances or cooling water in limited spaces, in package equipment for offshore services; and for atmospheric rainwater and oily water drainage service.

8.1.1.7.6.14 Threaded flanges may only be specified in Class 150 for service with non-hazardous substances and when indicated in the Piping Material Specifications of this reference standard.

8.1.1.7.6.15 Orifice plate flanges must be DN 50 (NPS 2) or larger, at least Class 300 and must comply with ASME 16:36:2009 or equivalent. The flange must have the same bore as the piping on which it is installed; see Fig. 5.

8.1.1.7.7. Valves 8.1.1.7.7.1 Valves for piping must comply with the recommended practices in API RP 615:2010 or equivalent, and for offshore facilities, with ISO 13703:2002 Section 6, but the requirements given in this reference standard shall prevail.

8.1.1.7.7.2

Valves must be specified according to and in conformance with ASME B16:34:2009 A standard Class series; ASME B16.10:2009 for dimensions between faces; ISO 5208:2008 for inspection and testing; and with the following standards as applicable, as well as the specifications given in this reference standard and each particular Piping Material Specification:

a) b) c) d) e) f) g) h) i) j) k) l) m)

Socket-weld or threaded- or welded-end gate, globe and check valves up to DN 50 (NPS2), ISO 15761:2002. Stainless steel or nickel alloy gate valves from DN 80 (NPS 3) up to DN 600 (NPS 24), API 603:2007 or equivalent. Carbon, intermediate- and low-alloy steel gate valves from DN 80 (NPS 3) up to DN 600 (NPS 24), ISO 10434:2004. Carbon steel globe valves DN 80 (NPS 3) and larger, ASME B16:34:2009 or equivalent, with body and stem thickness per ISO 10434:2004. Floating ball valves, API 608:2008 or equivalent. Trunnion-mounted ball valves, NRF-211-PEMEX-2008. Plug valves, NRF-142-PEMEX-2011. Butterfly valves DN 80 (NPS 3) and larger, API 609:2009 or equivalent. Check valves DN 80 (NPS 3) and larger, ASME B16.34:2009 or API 594:2010 or equivalents, as specified. Sliding solid parallel faced double-expanding gate valves, DN 600 (NPS 24) or larger, NRF-211PEMEX 2008. Emergency shutoff valves, NRF-204-PEMEX-2012. Needle valves, API STD 599:2007 or equivalent. Valves not covered by the standards mentioned in the preceding subparagraphs, ASME B16:34:2009 or equivalent.

8.1.1.7.7.3 The material of the valves' internals (trim) must comply with API Std 600:2009 or equivalent and API Std 602:2010, Table 12, or equivalent, as applicable, except for certain special severe services in which the Piping Material Specifications of this reference standard specify special trim materials with coatings such as chromium carbide and tungsten carbide, among others.

8.1.1.7.7.4 Valves should not have gaskets containing asbestos or materials that pollute the work environment.



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8.1.1.7.7.5 Valve materials must be steel or other alloys specified in ASME B16:34:2009 or equivalent, based on the service and as specified in the respective Piping Material Specification. The use of cast iron valves is not permissible, except for cement and barite service per 8.1.1.7.7.30 of this reference standard.

8.1.1.7.7.6 Valves must be specified as follows: a) b) c)

Gate, butterfly, ball or plug valves to isolate or shut off Globe or butterfly valves to regulate or throttle flow Check valves to prevent backflow

8.1.1.7.7.7. Flanged ends of valves must be built into the body and fabricated by forging or casting in a single piece (body-flange(s)). Valve flanges must comply with 8.1.1.7.6 of this reference standard.

8.1.1.7.7.8 Valve wheels must be solid. 8.1.1.7.7.9 Valves for service with hazardous substances must be specified for ultra-low emissions, classification C01, and for service with hazardous substances, with health risk level 4 in NOM-018-STPS2000 with a classification of at least CO2, in compliance with ISO 15848-1:2006. Valves must be marked as required in ISO 15848-1:2006, Paragraph 6.6.

8.1.1.7.7.10 Class 800 socket-weld or beveled-end gate, globe or check valves from DN 20 to 50 (NPS ¾ to 2) must comply with the f ollowing:

a) b) c)

Gate valves must have a fixed wheel, rising stem, bolted bonnet and solid wedge. Globe valves must have a wheel, rising stem and bolted bonnet. Check valves (no backflow) must be ball, piston or swing valves working in a horizontal or vertical position, with a bolted cover.

8.1.1.7.7.11 Class 150, 300 and 600 gate valves from DN 15 to 600 (NPS ½ to 24) with flanged or beveled ends must comply with the requirements of ISO 10434:2004 and must have a fixed wheel, rising stem, exterior thread, standard yoke and flanged bonnet, with the follo wing requirements for the ends:

a) b)

Flanged ends in DN 15 to 600 (NPS ½ to 24) Beveled ends in DN 80 to 600 (NPS 3 to 24) when indicated in the Piping Material Specifications of this reference standard.

8.1.1.7.7.12 Class 150, 300 and 600 gate valves larger than DN 600 (NPS 24) with flanged or beveled ends must comply with the requirements of ASME B16:34:209 or equivalent; and must have a fixed wheel, rising stem, exterior thread and standard yoke, flan ged bonnet and ends.

8.1.1.7.7.13 Class 600, 900 or 1,500 pressure seal gate valves with beveled ends must comply with the requirements of ISO 10434:2004 in DN 50 to DN 600 (NPS 2 to NPS 24), with fixed wheel, rising stem, seats with leak-tight seal, and ultralow-emission graphite gaskets. These valves must be specified for saturated and superheated steam service.

8.1.1.7.7.14 Gate valves for service in temperatures of -45 °C (-49°F) must comply with the requirements indicated in this reference standard for gate valves, have a 3.2 mm (1/8 in) diameter pressure-equalizing hole on the fluid-containing side face of the gate in order to have the same pressure in the bonnet cavity when the valve is closed; and the valve body must be marked with an arrow on the side with higher pressure as shown in Fig. 7.



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Valve with pressure hole in flexible wedge

Depressurized side

Flow, pressurized side

Flow

Figure 7. Pressure-equalizing hole in v alve gate. 8.1.1.7.7.15 Extended-bonnet gate and globe valves for service at design temperatures below ‒45°C or ‒49°F must comply with the requirements outlined in this reference standard for gate and globe valves, testing requirements and bonnet type in accordance with BS 6364:1984 or equivalent and the following. PEMEX will specify in the Service Specifications whether it requires the prototype test indicated in BS 6364:1984 or equivalent. a)

The extended bonnets of the valves may be one-piece or three-piece, mid-body flange extension - stuffing box, and in this case they must comply with the f ollowing requirements: - The flange of the bonnet for the extension must have a welding neck (equivalent to a welding neck reducer flange per ASME B16.5:2009) making it possible to join an extension and pipe of equal thicknesses. Unions between a flange and an extension without a neck that makes it possible to join equal thicknesses are not permissible; see Fig. 8. - The bonnet flange - extension pipe - stuffing box welds must be of the same thickness with bevel, complete penetration and 100 percent X-rayed. - The wall thickness of the extension must be compatible with the valve Class and within the mechanical strength requirements.

b)

Gate valves must have a 3.2 millimeter (1/8 in.) diameter pressure-equalizing hole on the fluidcontaining side face of the gate in order to have the same pressure in the bonnet cavity when the valve is closed; and the valve body must be marked with an arrow on the side with higher pressure, as shown in Fig. 7.



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Stuffing Extension pipe Equal thicknesses Bonnet flange with welding neck.

Welding without a neck is not acceptable

Fig. 8. Bonnet extension for gate and glob e valves. 8.1.1.7.7.16 Floating ball valves should only be specified up to DN 300 (NPS 12) in firefighting water service or services where hydrocarbons are not handled; or up to DN 50 (NPS 2) in services that handle hydrocarbons.

8.1.1.7.7.17 Unless otherwise specified, plug valves must be anti-static and designed as indicated below: a)

Class 150 - Short pattern in DN 50 to DN 300 (NPS 2 to NPS 12) - Venturi pattern in DN 350 to DN 600 (NPS 14 to NPS 24).

b)

Class 300 - Short pattern in DN 50 to DN 250 (NPS 2 to NPS 10). - Venturi pattern in DN 300 to DN 600 (NPS 12 to NPS 24)

c)

Class 600 -Regular pattern in DN 50 to DN 300 (NPS 2 to NPS 12).

8.1.1.7.7.18 Butterfly valves for process service must have flanged ends and be triple offset, API Std 609:2009 Category B or equivalent, with a wedge disc-stem connection unless otherwise indicated in the Service Specification or Piping Material Specification.

8.1.1.7.7.19 Wafer and lug butterfly valves are of limited use as jacketed valves only. These valves are permitted for DN 80 (NPS 3) and larger.

8.1.1.7.7.20 Jacketed lug butterfly valves must be double offset with a bolt circle, in DN 80 (NPS 3) and larger.

8.1.1.7.7.21 Pressure seal globe valves with beveled ends for saturated and superheated steam service must comply with the requirements of ASME B16:34:2009 or equivalent; the permissible classes are 600, 900 and 1500 in DN 50 to DN 300 (NPS 2 to NPS 12) with a fixed wheel, rising stem and seats with a leak-tight seal. In addition, the stem and the valve body wall thicknesses must comply with the requirements of ISO 10434:2004.

8.1.1.7.7.22 Extended-bonnet globe valves for service at temperatures below -45 °C (-49°F) must comply with the requirements indicated in 8.1.1.7.7.1, 8.1.1.7.7.2 and 8.1.1.7.7.15(a) of this reference standard and with testing and bonnet requirements per BS 6364:1984 or equivalent.



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8.1.1.7.7.23 Swing-type check valves must have flanged ends in Class 150, 300, 600, 900 and 1500 for DN 80 to 600 (NPS 3 to NPS 24); the design must include a stop built into the cover or body that limits the disc opening.

a) b)

Valves DN 80 to 600 (NPS 3 to NPS 24) must be Type B per API Std 594:2010 or equivalent. Valves larger than DN 600 (NPS 24) and up to DN 1050 (NPS 42) must be Type A per API Std 594:2010 or equivalent.

Stop

Stop

Note: These valves

Flow Disc or knuckle joint

Flow

must be installed in horizontal position in any service.

Fig. 9. Check valve with stop bu ilt into co ver or body. 8.1.1.7.7.24 "Non-slam" axial-flow check valves must comply with the requirements of ISO 14313:2007 and should be specified for the discharges of centrifugal compressors for process service.

8.1.1.7.7.25 Split-disc (dual-plate) check valves in Classes 150, 300, 600, 900 and 1500 must be Type A per API Std 594:2010 or equivalent. This type of valve should only be used for the Piping Material Specifications where so specified in this reference standard and its selection must be based on the following:

a)

Class 150 - Valves with flanged ends in DN 200 (NPS 8) and larger - Lug valves in DN 150 (NPS 6) and larger

b)

Class 300, 600, 900 and 1500 - Valves with flanged ends in DN 300 (NPS 12) and larger - Lug valves in DN 250 (NPS 10) and smaller

8.1.1.7.7.26 Check valves between flanges (wafer valves) are not permissible. 8.1.1.7.7.27 Pressure seal check valves with beveled ends for saturated or superheated steam service must comply with the requirements of ASME B16:34:2009 or equivalent with body wall thickness per ISO 10434:2004 in Classes 600, 900 and 1500 and DN 50 to DN 600 (NPS 2 to N PS 24).

8.1.1.7.7.28 Piston-type sampling valves must comply with the requirements of ASME B16:34:2009 or equivalent.

8.1.1.7.7.29 The valves indicated in Table 1 of this reference standard must have a gear and pinion actuator, with opening indicators.

8.1.1.7.7.30 Butterfly and check valves with grooved ends for cementing and barite service must be ND 80 to DN 200 (NPS 3 to NPS 8) with ductile iron body made of ASTA A395 Gr. 65-45-15 or ASTM A536 Gr. 65-45-12 or equivalents. Their use and application is restricted to these services, as established in the Piping Material Specifications of this reference standard.

8.1.1.7.8 Flanges for gaskets



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8.1.1.7.8.1 Gaskets must be specified to ensure leak-tight flanged connections. 8.1.1.7.8.2 Gaskets must comply with NRF-156-PEMEX-2008 and ASME B16:20:2007 or equivalent, and be of the type and material specified in the Piping Material Specification.

8.1.1.7.8.3 Gaskets must be free of asbestos and environmental pollutants. 8.1.1.7.8.4 Spiral-wound metal gaskets must have a centering (external) ring and, whenever it is a particular requirement of the Piping Material Specification, a backup (internal) ring. Spiral-wound metal gaskets must be identified as required in NRF-156-PEMEX-2008 with the proper color, both for the metal material and for the fill; see Fig. 10. The backup ring must be made of at least ASTM A240/A240M:2012 TP-304 or equivalent; the centering ring must be made of carbon steel, ASTM A36/A36M:2008 or equivalent with anticorrosion coating. Gaskets requiring different materials due to the service or acid, brine or corrosive environments are specified in the Piping Material Specifications of this reference standard.

8.1.1.7.8.5 R-type (RTJ) octagonal ring gaskets must be specified for hydrogen service and for Class 900 and larger, and must comply with N RF-156-PEMEX-2008.

8.1.1.7.8.6 Flat solid-metal gaskets (kammprofile) must have dimensions according to the Class and material specified in the project's Service Specifications, have an external centering ring and be identified as indicated in NRF-156-PEMEX-2008, Annex K, Table 1.

8.1.1.7.8.7 Non-metal gaskets should not be specified for metal piping. Type Valve DN

Diameter (NPS)

Class

Butterfly

200 150 100 400 300 250 200 150 200

(8) (6) (4) (16) (12) (10) (8) (6) (8)

and larger and larger and larger and larger and larger and larger and larger and larger and larger

300 600 900 and 1500 150 300 600 900 1500 150, 300 and 600

Ball

150

(6)

and larger

150, 300, 600, 900 and 1500

Plug, short pattern

200

(8)

and larger

150 and 300

Plug, Venturi pattern

350

(14)

and larger

150 and 300

Plug, regular pattern

100

(4)

and larger

600

Globe

Gate

Table 1. Use of rack and pi nion in valves [si c].



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Color marking to identify material

Metal spiral with fill material

Centering ring

Optional internal ring

Figure 10. Spiral-wound metal gasket 8.1.1.7.9 Studs and bolts 8.1.1.7.9.1 Piping studs, screws, bolts and nuts must comply with the requirements of NRF-027-PEMEX2009. Flanged connections must be made with studs or bolts and nuts; screws should not be specified for flanged connections.

8.1.1.7.9.2 In addition to 8.1.1.7.9.1, studs, bolts and nuts must comply with ASME B31.3:2010, ASME B16:5:2009 and ASME B18:31:2:2008 or their equivalents.

8.1.1.7.9.3 Studs and bolts must have conical or round pointed ends for immediate insertion into the threaded nuts and bolt holes. Bolts must be full body.

8.1.1.7.9.4 The length of the studs or bolts in flanged connections must be specified so that after they are tightened, they protrude by two or three threads on each end, which includes the threads of the pointed ends; see Fig. 11. U = Length of conical or rounded pointed end; not to be tightened past this point.

Fig. 11. Pointed end length 8.1.1.7.9.5 Studs, bolts, screws and nuts made of carbon or low- and intermediate-alloy steels with corrosion-resistant coating as required by PEMEX in the Service Specifications or Piping Materials Specifications included in this reference standard must comply with NRF-027-PEMEX-2007, ASME B1.1:2003, Section 7, or equivalent and the following maximum working temperature limits:

a) b)

Zinc-based coating, up to 210°C (410°F). Cadmium-based coating, up to 160°C (320°F)


c)


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Polytetrafluoroethylene (PTFE)-based coating, up to 260°C (500°F)

8.1.1.7.10 Figure eights, spacers and blinds 8.1.1.7.10.1 The spacing required for the installation and operation of figure eights, spacers and permanent blinds to block off piping and equipment must be specified from the design stage.

8.1.1.7.10.2 Figure eights, spacers and blinds must comply with ASME B16:48:2010 or equivalent for the piping Class in question. The sizes not covered by ASME B16:48:2010 or equivalent must be calculated in accordance with ASME B31.3:2010 Paragraph 304.5.3 and dimensions must be compatible with the dimensions of the flanges where the y are to be installed. Figure eights m ust be specified for diameters up to DN 300 (NPS 12), and a two-piece spacer and blind for larger diameters.

8.1.1.7.10.3 Cast figure eights, separators and blinds or those made of plate should not be specified for Class 900 and larger.

8.1.1.7.10.4 In figure eights, spacers and blinds, the sealing surface of the gasket must have the same finish, rise and dimensions as the faces of the flanges where they are installed in accordance with ASME B16:5.2009 or ASME B16.47:20011, Series A, as applicable. The thickness of the raised face or groove, as applicable, must be added to the required thickness as calculated or indicated in ASME B16.48:2010 or equivalent.

8.1.1.7.10.5 Figure eights, spacers and blinds must be stamped on the edges with the DN, Class and material specification; and for those not covered by ASME B16.48:2010 or equivalent, also with the permissible maximum working pressure and the corresponding temperature. For figure eights, the marking must be on both sides (blind side and free side).

8.1.1.7.10.6 Spacers and blinds must have a pad-eye lifting lug. The lifting lug of the blinds must be located on the normal axes of the piping (0 °, 90°, 180° or 270°) that passes between the space of the studs or bolts. The lifting lug of the spacers must also have an eye that matches the bolt circle and bolt hole diameter of the flanges, which must be located to coincide with the first stud or bolt of the flanged connection per Fig. 12. Spacer

Blind Blind lifting lug

Spacer lifting lug

Stamp the DN, Class and material on the ed es.

Figure 12. Spacers and blin ds

Bolt hole matching the bolt circle and bolt hole diameter of the flanges.



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8.1.1.7.10.7 The lifting lug must protrude at least 10 cm from the flanges and each of its faces must be stamped "CIEGO” (BLIND) for the blinds and "LIBRE” “(FREE) for the spacers. The marks must not be hidden by the flanges; see Fig. 12.

8.1.1.7.10.8 When frequent operation of the figure eights is anticipated in service with hazardous substances and/or where a leak would put the facilities at risk, manual (lever-operated) or automatic sliding shutters between flanges may be specified at the request of PEMEX and stipulated in the project's Service Specification in order to allow safe changes of plate position without the need to dismantle the flanges. These devices must be flanged and comply with the dimensions given in ASME B16.5:2009 or ASME B16.47:2001, Series A, as applicable.

8.1.1.8 Non-metal piping 8.1.1.8.1 Non-metal piping must only be specified when requested by PEMEX in the Service Specification with the pertinent Piping Material Specification.

8.1.1.8.2 The design of non-metal piping must comply with ASME B31.3:2010 and this reference standard, and include at least the following:

a)

b) c) d) e) f) g) h) i) j) k) l)

The inside diameter must have a cross-section area commensurate with a velocity and flow similar to that required for metal piping and use the factory connections required to tie in with metal piping where specified. Since non-metal piping has a greater thickness than steel piping under the same working conditions, it must have a larger diameter to offer with the same velocity and not worsen pressure losses. Necessary service life of the facility and deterioration during that time. Expected extreme environmental conditions. Long-term shear strength and modulus of elasticity at design temperature that match the lifetime of the facility. Thermal expansion coefficient. Flexibility analysis that includes the design of expansion curves and necessary anchors in the transition zone with the union with metal piping. The mechanical transition joint between metal and non-metal piping must be designed with factory parts. Cast iron piping components should not be specified. In connections with LJ flanges, the stub end material must have the same specification as the non-metal pipe. Calculate the pipe's long-term resistance to overpressures (water hammer, recurrent and occasional sudden surges, greater risk conditions for the firefighting system, among others) in the piping system that matches the service life of the facility. The hydrostatic design stress must be confirmed by the manufacturer with destructive laboratory tests, delivering the results report issued by an accredited laboratory in terms of the Federal Standards and Measures Act. Pipes and piping components must be tested and approved by FM and bear the mark "FM." Pipes and piping components for the firefighting system must be listed for firefighting service by the UL or equivalent.

8.1.1.8.3 Underground pipin g for firefighti ng systems 8.1.1.8.3.1 Non-metal piping for underground installation in firefighting systems is only permissible when requested by PEMEX in the pertinent Service Specification for the project, and must comply with this reference standard, applicable Piping Material Specifications and design criteria given in NRF-016PEMEX-2010.

8.1.1.8.3.2 The installation of fiberglass piping must comply with ISO/TS 10465-1:2007.



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8.1.1.8.3.3 High-density polyethylene piping must have a nominal pressure of 1.72 MPa (250 psi) and a DR (diameter-thickness) ratio of 7.3 per ASTM F2619/F2619M:2011 or equivalent.

8.1.1.8.4 Piping for firefighti ng sys tems in o ffshore facilit ies. 8.1.1.8.4.1 Non-metal piping for firefighting water in offshore facilities is only permissible when requested by PEMEX in the pertinent Service Specification for the project and must comply with this reference standard, the applicable Piping Material Specification and design criteria given in NRF-016-PEMEX-2010.

8.1.1.8.4.2 Any fiberglass piping that is specified must comply with at least the following: a) b) c) d) e)

A seawater-resistant liner at least 0.0254 mm (0.001 in.) thick. Hydrostatic design pressure of 48.26 MPa (7000 psi). Exterior intumescent coating for jet fire resistance of at least 5 minutes with the piping empty and 20 minutes with the piping packed, signal red in color. The winding angle of the reinforcement fiber must be 54.7°. The piping must comply with ISO 14692-1, 2, 3 and 4:2002.

8.1.2

Design of pipin g arrangements

8.1.2.1 General requi rements 8.1.2.1.1 When PEMEX so specifies, piping engineering must be prepared with the use of intelligent 3-D electronic models, which must comply with NRF-107-PEMEX-2010.

8.1.2.1.2 The spacing between onshore facilities or plants and between equipment must comply with the applicable approved-for-design equipment layout of the project.

8.1.2.1.3. Piping arrangements and distribution must be grouped and ordered so that installation is functional, simple, safe and economic, and should facilitate constructability, operation and maintenance, as well as provide the necessary space for access and emergency escape routes.

8.1.2.1.4 Provisions for future expansions must be made with an isolation valve (root or shutoff valve) and blind flange downstream; figure eights and blinds should not be used in these cases.

8.1.2.1.5 For splitting streams where figure eights or blinds must be installed, isolation valves should be specified before them.

8.1.2.1.6 Figure eights and blinds should not be specified for piping terminal points. 8.1.2.1.7 Piping must rest on piping supports; for onshore facilities, supports must comply with NRF-139PEMEX-2012.

8.1.2.1.8 Piping arrangements should not include dead legs. 8.1.2.1.9 Where purges must be installed, the height between the finished floor level and the bottom span of the pipe must be at l east 40 cm, except as indicated in 8.1.2.6.3 and 8.1.2.1.14.

8.1.2.1.10 The minimum height of the bridges must be as given in NRF-139-PEMEX-2012.



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8.1.2.1.11 The minimum obstruction-free height between the finished floor level or operating level (as applicable) and the bottom span of the structure must be as shown in Table 2.

8.1.2.1.12 Underground piping is only permissible for drainage, cooling water, utility water, drinking water and firefighting water service and collection and recovery systems. Any other service must be overhead. Piping for firefighting water must also comply with NRF-015-PEMEX-2008 and NRF-016-PEMEX-2010. Underground metal piping must only be specified with welded joints.

Description

Onshore facilities

Offshore facilities

Minimum height of elevated supports, piping corridors i nside the 3.00 m 2.20 m plant limit. Over platforms and walkways 2.40 m 2.20 m Inside buildings (compressor house, pump house, among others) or 2.40 m 2.10 m within a common group of equipment Note: In all cases, sufficient space must be provided to remove and/or access the equipment.

Table 2. Minimum height of structural supports 8.1.2.1.13 Underground piping for gravity collection and recovery of reusable substances such as amine, muriatic acid (HCI), MTBE/TAME and methanol, among others, must be lai d in trenches.

8.1.2.1.14 Piping laid in trenches must be supported on blocks that must allow runoff into rainwater drains and/or the applicable drainage, depending on the service of the lines, with a gap of at least 10 cm between both sides of the block and the walls and a minimum height of 15 cm.

8.1.2.1.15 Trenches must have galvanized grates, concrete covers or railings, as specified in the project, in order not to leave hazardous conditions for the personnel. Piping that handles explosive fluids whose vapors are heavier than air should not be laid in trenches.

8.1.2.1.16 When vents and drains are integrated into a closed system in the design, they must include figure eights.

8.1.2.1.17 Services for the purging and draining of liquids must be piped to oily or chemical drainage or a closed system; arrangements with purges into the ground or the atmosphere are not permissible.

8.1.2.1.18 Purges, drains or vents of hazardous substances or environmental pollutants must be tied into closed systems.

8.1.2.1.19 Piping arrangements must include the interlocks needed to allow safe sectioning or isolation for shutdown, maintenance and inspection of the facilities, so that blocking off one does not affect the operation of the others.

8.1.2.1.20 Piping arrangements must allow quick and easy access to equipment and instruments for operation and maintenance.

8.1.2.1.21 For piping that operates at high temperatures and requires a thermal insulation system, this system must comply with NRF-034-PEMEX-2011.



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8.1.2.1.22 For piping that operates at low temperatures and requires a thermal insulation system, this system must comply with NOM-009-ENER-1995, ISO 1224 1:2008 and the particular specification for the project.

8.1.2.1.23 Piping with no thermal insulation system and an operating temperature higher than 59 °C (139°F) or colder than -5 °C (23°F) in areas where personnel may come in contact with it must have a barrier installed for their protection per NRF-034-PEMEX-2011.

8.1.2.1.24 Barriers in coastal or offshore facilities must be made of aluminum for marine environments, ASTM B928 Alloy 5083 or equivalent.

8.1.2.2 Spacing b etween pipi ng 8.1.2.2.1 For ease of removal and repair, piping must have at least the following separations (see Fig. 13):

a)

Onshore facilities; •

•

•

•

b)

In flangeless piping, 80 mm between pipe/pipe or pipe/insulation, pipe/wall and insulation/wall spans. In flanged piping, 50 mm between pipe/large diameter flange, pipe/flange insulation or insulation/flange spans. 150 mm between non-insulated flanges and the adjacent wall or equipment, or 80 mm between insulated flanges and a wall. In hookup piping at onshore industrial plants, 150 mm between piping spans.

Offshore facilities: •

•

•

In flangeless piping, 50 mm between pipe/pipe or pipe/insulation, pipe/wall and insulation/wall spans. In flanged piping, 50 mm between pipe-large diameter flange, pipe-flange insulation or insulation/flange spans. 80 mm between non-insulated flanges and the adjacent wall or equipment, or 50 mm between insulated flanges and a wall.

Flanges should not be aligned in parallel piping; they should be staggered.

8.1.2.2.2 In parallel piping subject to thermal expansion or contraction, the minimum separation between piping must be greater, depending on the flexibility analysis in order to prevent contact or interference during operation, startup or shutdown.

8.1.2.2.3 Piping arrangements must include additional space required for thermal insulation or a personnel protection system.

8.1.2.2.4 The location of piping in pipe racks must be optimized by DN, temperature and service. a) b) c)

Larger DN piping should be housed next to the columns. Smaller DN piping in the center. Piping in hot service should be located on the side opposite piping in cold and cryogenic service, as shown in Fig. 14.

8.1.2.2.5 If two tiers of piping are required, the utilities and vents should be located on the top tier and the process piping on the bottom tier. When three or more tiers are required, the vents should be located on the top tier, the utilities on the middle tiers, and the process piping on the bottom tier, as shown in Fig. 15.



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Equipment or wall

150/80 mm or 80/50 mm

A = 50 mm minimum 150 mm minimum

Fig. 13. Minimum separation between piping (the flange sets of parallel piping m ust be staggered) Hot piping

Cold piping

Fig. 14. Piping dis tribut ion in a single tier 8.1.2.2.6 The separation between underground piping must be at least 45 cm. 8.1.2.2.7 Where there is no vehicle traffic or crossings or loads on the ground, the depth of the underground piping should be no less than 45 cm measured from the top of the pipe to the finished floor level. At street, road and railroad crossings or where loads on the ground are expected, the depth should be no less than 1 m, and the design must have a carbon-steel metal jacket complying with the recommendations of API RP 1102:2007 or equivalent.

8.1.2.2.8 Piping arrangements must leave free spaces around and between vessels, equipment and piping to provide access for portable maintenance equipment. Operating space between piping and the adjacent equipment must be at least 75 centimeters and should not obstruct walkways or passageways.

8.1.2.2.9 Piping with liquid sulfur, vents and processes with liquids formed by condensation must be designed with a continuous slope. Vent and process drain points must empty into a vessel or collector head. The necessary adjustments should be made to the saddles, respecting the integrity of the piping supports. Pockets, dead legs or arrangements allowing the accumulation of liquids that limit or hinder the free flow of gases or might cause backpressure and/or localized corrosion points are not permissible.



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Vent piping

Utility piping

Process piping

Fig. 15. Distribu tion of tiers on pi ping supp orts 8.1.2.2.10 Piping that requires a slope or free drain of the liquid must have a minimum slope of 1:1000 (1 mm per meter). If a steeper slope is required, it should be specified in project engineering.

8.1.2.2.11 The design of the electrical trace heating system must comply with NRF-248-PEMEX-2010. 8.1.2.2.12. For process gas services in sulfur plants, the minimum slope must be 4:1000 (4 mm per meter) and for liquid sulfur service, 20:1000 (20 mm per meter). If a steeper slope is required, it must be specified in project engineering.

8.1.2.2.13 Drainage systems must comply with NRF-1 40-PEMEX-2011. 8.1.2.3 Filters The piping filters in the Piping Material Specifications of this reference standard are typical for the respective service; specifying the filters in compliance with the following and the Service Specification is the responsibility of the Contractor in consultation with PEMEX.

a) b) c) d) e)

The mesh material must be resistant to the fluid and made of at least 304 stainless steel. Type of fluid and physical-chemical properties (composition, density, viscosity, corrosiveness, hazard level, incompressible and compressible, among others). Process conditions (flow and velocity, pressure and pressure drop, as well as operating temperature). Type of service, application, operation, cleaning and maintenance. Operation periods without cleaning or replacing elements, with respect to the quantity of suspended particles and size of particles to be filtered out.

8.1.2.4 Change of specification Changes of Piping Material Specifications must be made as follows:

a)

Changes involving Class and/or similar materials (same group No. P of ASME B31.3.2010) must be made for the welded union of flanges; see Fig. 16.


b) c)


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Changes involving Class and/or dissimilar materials (different group No. P of ASME B31.3.2010) must be made for the flange. In both cases, the Piping Material Specification with the higher class and superior alloy for gaskets and bolts is to prevail. Change involving Class and/or similar materials Class 150

Class 300

Change involving Class and/or dissimilar materials Class 300 Class 150

Fig. 16 Change in Piping Material Specifications for automatic valves 8.1.2.5 General requi rements f or valv e arrangements 8.1.2.5.1 Control valve arrangements must have bypass passages that will include two manual shutoff valves, one on each side, and one direct or bypass passage with a valve to keep the piping system in operation. The valve in the direct or bypass passage must be of the same diameter as the control valve and should be as close as possible to the lowest pressure tee, unless the Licensor indicates otherwise.

8.1.2.5.2 Valves at a height above 4.5 m must have platforms and fixed stairways to operate them, except for ND 50 (NPS 2) and smaller root valves attached to headers.

8.1.2.5.3 In onshore facilities, frequently operated valves should be located so that they can be operated from the finished floor level or from an operating platform at a height of no more than 1.9 m, as indicated in Fig. 17.

8.1.2.5.4. In offshore facilities, frequently operated valves at heights above 1.9 m must be specified with rapid-action hammer-blow chainwheels, with the exception of DN 50 (NPS 2) and smaller root valves attached to the header.

8.1.2.5.5 Infrequently operated valves installed at heights above 2.1 m and up to 4.5 m must be accessible through adjacent fixed platforms, articulated platforms or fixed stairs. Articulated platforms must comply with NRF-268-PEMEX-2010.

8.1.2.6 Valves at battery boundaries must have sufficient space for their operation and maintenance, with fixed stairs for access on each side of the piping support and fixed platforms.

Standards Committee Petróleos Mexicanos and Subsidiaries STEMS WTH ANGLE OF ROTATION HEIGHT FROM CENTER OF WHEEL

VERTICAL STEMS HEIGHT FROM CENTER OF WHEEL


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NOTES: 1. IF DESIGN CHARACTERISTICS ALLOW, IT IS PREFERABLE TO INSTALL VALVES WITH THE STEM VERTICAL BECAUSE THIS GREATLY FACILITATES MAINTENANCE (LUBRICATION, INSPECTION, REPACKING). THEY MAY BE INSTALLED WITH THE STEP HORIZONTAL, BUT NOT TURNED DOWNWARD BECAUSE THE BONNET WOULD ACT AS A TRAP FOR ABRASIVE SEDIMENTS AND LIQUID THAT COULD FREEZE, DAMAGING THE VALVE. 2. VALVES INSTALLED ABOVE PLATFORMS AND/OR PASSAGEWAYS WILL BE LOCATED AT A MINIMUM HEIGHT OF 0.340 M. 3. VALVES REQUIRING FREQUENT AND/OR EMERGENCY OPERATION IN WHICH THE STEM CENTERLINE IS HIGHER THAN 19 M ABOVE THE FLOOR OR PLATFORM LEVEL WILL BE INSTALLED WITH RAPID-ACTION HAMMER-BLOW CHAINWHEELS . THEY WILL NOT BE USED IN THREADED VALVES. IN THE ABSENCE OF SUCH OPERATING CONDITIONS, THEY WILL BE INSTALLED SO THAT THEY CAN BE OPERATED FROM PORTABLE STAIRWAYS OR FROM THE PIPING TIERS. 4. GATE VALVES IN PUMP DISCHARGE PIPING WILL BE LOCATED SO THAT THEY CAN BE NORMALLY OPERATED FROM THE FLOOR. THE MAXIMUM PERMISSIBLE HEIGHT TO THE STEM CENTERLINE WILL BE 175 M. WHEN THE VALVE CANNOT BE SERVICED DUE TO DESIGN REQUIREMENTS, IT WILL BE INSTALLED WITH THE DEVICES MENTIONED IN POINT 3. 5. FOR FABRICATION DETAILS, SEE THE MANUFACTURER'S MANUAL. 6. DIMENSIONS ARE GIVEN IN METERS.

HORIZONTAL HEIGHT FROM CENTER OF STEM THE CHAIN SHOULD NOT HANG IN PASSAGEWAYS

MAXIMUM HEIGHT FOR VERTICAL STEMS

ALTERNATIVE W/ ANGLE OF ROTATION

FREE SPACE FOR HEAD

CHAINOPERATED VALVE

MAXIMUM HEIGHT FOR DISCHARGE VALVES IN PUMPS

FACIAL DANGER ZONE VALVE STEMS ARE NOT ALLOWED TO PROTRUDE. THEY MUST BE COVERED BY EQUIPMENT AND/OR PIPING

FIRST ALTERNATIVE

SECOND ALTERNATIVE

DANGER ZONE EXTENSIONS FOR WHEELS (NOTE 5)

ONLY ACCEPTABLE FOR VALVE MAINTENANCE

COLUMN OR RAILING

VALVE STEMS ARE NOT ALLOWED TO PROTRUDE. THEY MUST BE COVERED BY EQUIPMENT AND/OR PIPING

MAX. HORIZONTAL DISTANCE OPERATOR

FLOOR OR PLATFORM LEVEL

Fig. 17. Location o f frequently operated valves 8.1.2.5.7 At supports for hook-up piping, fixed marine-type stairways must be installed at the start of the piping support and every 50 meters along its length. At piping supports inside plants, two additional marine-type fixed stairways must installed at the battery boundaries, one at the end opposite the battery boundary and another in the middle.

8.1.2.5.8 The passageways or areas where personnel circulate must be free of any obstructions, with a clear width of at least 70 cm. Valve wheels, handles, stems and actuators, among others, should not extend into this area.

8.1.2.5.9 The orientation of wheels, handles, stems and actuators must be indicated on the piping isometrics and/or drawings, and in the 3D electronic model when applicable.

8.1.2.5.10 In parallel equipment or facilities for the same function, separate shutoff valves must be installed to isolate the equipm ent or facilities for maintenance, without interrupting normal plant operation.



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8.1.2.5.11 Valves housed in manholes or trenches (under cover) must be specified with wheeled stem extensions for operation from a finished floor level of approximately ± 10 cm, with an open/closed position indicator that displays the valve's position outside the manhole or trench as shown in Fig. 18; except for valves in manholes with depths and dimensions allowing them to be operated inside by personnel standing upright.

Fig. 18. Valves housed in trenches 8.1.2.6 Piping arrangement in heat exchangers 8.1.2.6.1 The inlet and outlet piping of heat exchangers must include manually operated shutoff/isolation valves and figure eights for their isolation, unless the Licensor or risk assessment indicates otherwise. The location of the valves and figure eights must be accessible from the operating floor or platform level; see Fig. 19.

8.1.2.6.2 Valves in vents or drains located in the inlet or outlet piping of heat exchangers must be at least DN 25 (NPS 1).

8.1.2.6.3 The distance between the bottom of the piping under the heat exchangers and the operating floor level must be at least 50 cm.

8.1.2.6.4 Piping arrangements must be designed so that in the event of flow failure, the heat exchangers remain full of cooling fluid.

8.1.2.6.5 The piping arrangement in heat exchangers must allow removal of the tube bundles, covers, channels and bonnets; the free space in front of the equipment for this operation must be at least the length of the tube bundle plus 1 m.



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Venting Figure eight

Heat exchanger

Figure eight

Manually operated shutoff valves

Fig. 19. Piping arrangement in heat exchangers 8.1.2.7 Piping arrangement in process compr essors 8.1.2.7.1. Suction and discharge piping must have manually operated shutoff valves and figure eights, accessible from the operating floor level or from platforms.

8.1.2.7.2 Utility piping for the compressors must have manually operated shutoff valves. 8.1.2.7.3 At onshore facilities, the arrangement and distribution in the process compressor house must have a mezzanine, with the compressor in the top part and the utilities in the bottom part, unless a different arrangement is indicated in the project's Service Specification.

8.1.2.7.4 Compressor discharge piping must have a non-slam axial flow check valve. 8.1.2.7.5 Compressor suction piping must have filters, and the piping arrangements should allow easy removal. Filters must be accessible from the operating f loor level or from operating platforms.

8.1.2.7.6 Piping arrangements must have vents and purges to release pressure. Process gases must be sent to venting.

8.1.2.8 Piping arrangement in pumps 8.1.2.8.1 In suction and discharge piping, the manually operated shutoff valves must be accessible to personnel and as close as possible to the pumps in order to reduce the volume of the purged product, and must have figure eights; see Fig. 20.

8.1.2.8.2 Piping arrangements for swing-type check valves must be for operation in horizontal p osition. 8.1.2.8.3 Piping arrangements must leave space that allows access for maintenance work, equipment removal and filter cleaning.



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8.1.2.8.4 In the design of piping arrangements, the eccentric reducer on the pump suction side must be with the flat face (flat side) up, as shown in Fig. 20.

8.1.2.8.5 The design of pump suction piping must include a final filter with a purge that is removable with no need to disconnect the piping. Permanent conical filters are not acceptable. Purges must be specified for the lowest point of the pi ping.

8.1.2.8.6 Compatible pump purges should be grouped in a common header and connected to the appropriate drainage.

8.1.2.9 Piping arrangement in towers and vessels 8.1.2.9.1 Piping arrangements in fractionating towers must have a slope of at least 2 percent to ensure a free drain toward the process equipment (condenser and accumulator, among others), as shown in Fig. 21.

8.1.2.9.2 Nozzles for process utilities must be oriented toward the plant's piping racks.

Discharge valve

Figure eight

Venting

Check valve

Eccentric reducer

Figure eights

Filter Purges Cup or closed drainage

Fig. 20. Typical pipi ng arrangement at pumps (Figure does not impl y a specific design)



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8.1.2.9.3 Valves, instruments and inspection boxes, am ong others, must be accessible from platforms and conform to NRF-028-PEMEX-2010.

Fractionating Column

2% slope allowing free drain of condensates

Condense

Fig. 21 Piping arrangement in fraction ating column

8.1.2.10 Piping arrangement f or air service (breathing , instruments, pl ants, seals, comb ustion ) 8.1.2.10.1 The discharge piping of compressors or blowers must have manually operated shutoff/isolation and check valves.

8.1.2.10.2 At offshore facilities, the check valve in the blower discharge must have a dual plate, with reinforced springs made of UNS N07750 m aterial or equivalent.

8.1.2.10.3 The blower suction piping must be stainless steel from the filtering system outlet nozzle up to the blower nozzle, preventing the formation of rust or scale on the steel and damage to blower internals.

8.1.2.10.4 The piping system for breathing air must be a dedicated system independent of air piping for other services. The breathing air piping system must be sanitary grade from the conditioning package up to the breathing air outlet stations. Air quality must be for human consumption and comply with CGA-G72008 and CGA-G7-1-2011 or equivalents.

8.1.2.10.5 Breathing air taps must be DN 25 (NPS 1) with 4 DN 8 (NPS ¼) quick connects, with latch. See Fig. 22.

8.1.2.10.6 Compressor and blower air taps must be located and oriented to facilitate the entry of contaminant-free air. The design must keep out rain and animals.

8.1.2.10.7. Plant and instrument air headers in hookups must have a slope toward the drainage points at the low points and at air header elevation changes. The drainage arrangement must have a shutoff valve and condensate trap at floor level.



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Air flow Quick connects

Latch for connectors

Fig. 22. Piping arrangement at breathing air taps

8.1.2.11 Piping arrangement at battery boundaries 8.1.2.11.1 All piping at battery boundaries must have a shut/off isolation or double valve as required in 8.1.2.11.2.

8.1.2.11.2 Battery boundary arrangements for process, fuel gas and steam piping or piping with hazardous substances with Level 3 risk or higher must have a manually operated double shutoff/isolation valve and figure eight, as well as a purge, drain or vent, as applicable, as shown in Fig. 23.

8.1.2.11.3 Battery boundary arrangements for Class 300 piping or higher or for working temperatures of 100°C (212°F) must have an equalizing line, as shown in Fig. 23.

8.1.2.11.4 Piping arrangements at battery limits must include a figure eight to ensure isolation of the facility. In the case of the double valve, it must be installed after the second or between the two valves when there is a particular requirement of Pemex. The valve/figure eight arrangements must be accessible to the personnel.



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Figure eight

Hookup side

Isolated facility side

Figure eight

Fig. 23. Double shutof f with valves at battery bou ndary 8.1.2.12 Piping arrangement for direct-fired heaters 8.1.2.12.1 The design of piping arrangements for (process) fuel gas must include a manually operated shutoff/isolation valve and an automatic shutoff valve in the process side supply stream to the heater, as well as a manual shutoff/isolation valve and a check valve in the outlet stream.

8.1.2.12.2 Valves must be located at least 15 m from the direct-fired heater, measured horizontally as shown in Fig. 24, and must include connections for the instrumentation required for project equipment.

8.1.2.12.3 Taps for furnace hearth or direct-fired heater blowdown steam must be included, as well as a ring to form a steam curtain on the p eriphery of the equipment.



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FSDH = High-flow trip FSDL = Low-flow trip FR = Flow recorder

Partition SDV = Remote-operated isolation valve (emergency shutoff valve)

Manual shutoff valve

TI = Temperature indicator

TSDH = Hightemperature trip

15 meters DH=Pressure relief valve to vent

High-temperature trip

TRC = Temperature recorder control

Check valve

PSDL = Lowpressure trip Direct-fired heater

Fig. 24. Piping arrangements for d irect-fired heaters

8.1.2.14.4 The design of fuel gas piping arrangements must include manually operated shutoff/isolation valves upstream from the pilot and burner fuel gas skid. The valve must be a quick open/close (¼ turn) ball valve located at least 15 m from the direct-fired heater, measured horizontally as shown in Fig. 25. Arrangements should also include the valves and connections required for project equipment.



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Hearth of directfired heater Pilot

Burner

15 m min. between furnace and ESDV

TCV = Temp. control valve

FR = Flow recorder PI = Pressure indicator

PSDH = Highpressure trip

ESDV = Emergency shutdown valve

PSLD = Lowpressure trip

Fig. 25. Fuel gas piping arrangement

8.1.2.13 Vent pi pin g arrang ement 8.1.2.13.1 Piping arrangements for the installation of pressure relief valves and venting systems must comply with NRF-031-PEMEX-2011, ASME B31.3-2010 paragraph 322.6 and the following:

8.1.2.13.2 Horizontal piping must have a s lope that allows the free drain of liquids and condensates to the accumulator or seal tank.

8.1.2.13.3 Piping must not have pockets, dead legs or arrangements that accumulate liquid, create backpressure, or limit or hinder the free flow of gases and liquids.

8.1.2.13.4 Branch connections in the headers must be designed with a 45 ° angle at the top of the header in the direction of flow as shown in Fig. 26, and must be made of line and/or factory components (not improvised).

8.1.2.13.5 Pressure relief valve discharges must be tied into the venting header to prevent the accumulation of condensates that could cause overpressure in the valve d ischarge and corrosion of valve internals and the piping, as shown in Fig. 26. If not feasible, then as an exception and at the specific request of PEMEX in the Service Specification, the pressure relief valve discharge piping must be selfdraining to prevent the accumulation of liquids downstream from relief valves, complying with API RP 520 Part II:2003 or equivalent.



Shutoff at top of header Pressure relief valve located on venting header

Sloped piping

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Integrally reinforced connection or Y fitting

Branch connection into venting header

Venting header Shutoff valve

To venting header Sloped piping to ensure free drain of liquids

Equipment or piping to be protected

Fig. 26. Relief valv e arrangement 8.1.2.13.6 Piping arrangements for pressure relief valves on equipment that must not be left unprotected under any circumstances, such as storage spheres, reactors and distillation columns, among others, must have two relief valves with a 100 percent pressure relieving capacity each, and unless otherwise indicated by PEMEX or the Licensor in the Service Specification, with 2-position 3-way valves for selecting the pressure relief valve, which m ust comply with API RP 520 Part II:2003 or equivalent.

8.1.2.13.7 Piping arrangements for pressure relief valves due to thermal expansion of heat exchangers must have a manually operated shutoff/isolation valve with discharge piping to a drainage cup or, if applicable, per 8.1.2.13.5.

8.1.2.13.8. Pressure relief valves that discharge into the atmosphere should only be specified for substances that do not pollute the environment, such as steam or air, and must discharge to an elevated location that is safe for the personnel. They must also have a 6.4 mm (1/4 in.) diameter orifice at the lowest point, as shown in Fig. 27.

Discharge to safe location

Pressure relief valve 6.4 mm (¼ in.) orifice at lowest point

Fig. 27. Pressure relief valve to atmosphere



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8.1.2.14 Basic Nippl e Arrang ements 8.1.2.14.1 The basic nipple arrangements for process services or hazardous substances must consist of the following: a) b) c)

Integrally reinforced connection (nipolet or nipple pipet) plus valve, nipple and plug. Integrally reinforced connections such as a sockolet plus nipple, valve, nipple and plug. Integrally reinforced connections such as a valvolet plus nipple and plug.

8.1.2.14.2 All vents, drains and purges must be piped to safe discharge points per 8.1.2.15, with a plug or flanges as applicable.

8.1.2.14.3. Integrally reinforced connections (nipolet or nipple pipet) must have a minimum length of 90 mm (3.5 in) for piping without a thermal insulation system and a maximum length of 165 mm (6.5 in.) for piping with a thermal insula tion system so that the valve actuator is n ot obstructed.

8.1.2.15 Vent, dr ain and purg e arrangements 8.1.2.15.1 Purges, drains and vents must comply with 8.1.2.1.16-18 and the basic nipple arrangement in 8.1.2.14, with the exception of the arrangements required by the L icensor's specifications.

8.1.2.15.2 Purges, drains and vents in Class 600 and higher piping must be specified with a manual double shutoff/isolation valve. Class 600 piping must have two gate valves, and Class 900 and higher piping must have one gate and one globe valve.

8.1.2.15.3 For the hydrostatic test, the piping must have drains at the lowest points and vents at the highest points, with an integrally reinforced connection (threadolet) plus nipple and valve. After the hydrostatic test, the nipple and the valve should be removed and a solid-bar plug installed, applying a weld bead to the threaded connection to seal it.

8.1.2.15.4 For piping purges, drains and vents in services with dirty substances that entail a risk of plugging, the basic nipple arrangement should be replaced with piston valves with a built-in coupling. In closed position, the valve piston should be flush with the inner wall of the piping.

8.1.2.15.5 Inside plants, the purges and drains must be piped to drains based on the service. Purges and drains should not be discharged i nto the atmosphere or the ground.

8.1.2.15.6 Piping arrangements must have enough space that the purge valves can operate without obstructions or maneuvers that put personnel at risk.

8.1.2.15.7 "L" drain arrangements or arrangements in more than one plane must be kept to a minimum. When they are unavoidable, a support must be installed to prevent overstressing that could damage their mechanical integrity. They should preferably be aligned under the longitudinal axis of the piping.

8.1.2.16 Arrangements for instrument taps 8.1.2.16.1 Arrangements for instruments should allow the instrument to be removed, leaving the piping in operation and not exposing personnel to substances. Arrangements must have an isolation, purge and/or vent valve and comply with API RP 551:1993 or equivalent.



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8.1.2.16.2 The arrangement for pressure gauges must have a gate valve to the header and a purge or vent valve that allows for bl eeding pressure from the gauge.

8.1.2.16.3 Arrangements for instruments should be designed with a nipolet or nipple pipet with a gate valve, per Piping Material Specification. This type of arrangement does not apply to flanged instruments. The arrangement downstream from the valve should be supplemented as specified in the applicable typical instrument installation arrangement.

8.1.2.17 Arrangements for sampling taps 8.1.2.17.1 Arrangements for sampling taps must allow sampling while the piping is in service, without exposing personnel to substances. Arrangements must have a shutoff, purge and/or vent valve per 8.1.2.15 and the type of sampling device.

8.1.2.17.2 Liquid sampling taps in horizontal piping must be in the middle of the piping to ensure that there is no interference from gases.

8.1.2.17.3 Gas sampling taps in horizontal piping must be in the top part of the piping to ensure that there is no interference from liquids.

8.1.2.17.4 The typical arrangement for a conventional sampling tap must conform to the following unless PEMEX or the Licensor indicates otherwise:

a)

It must have a minimum interior projection of 25 mm into the pipe as shown in Fig. 28.

b)

In clean fluids, the sampling control valve must be a ¼-turn ball valve equipped with a spring return ("deadman") handle that ensures safe closure. The allowable diameters are DN 8 and DN 15 (NPS ¼ and NPS ½), with ASME B1.20.1-1983 or equivalent threads made of ASTM A182/A182M-11 Gr. F316 stainless steel in Class 3000 or higher.

c)

For purges and sampling taps in piping or vessels that contain liquids with sudden vaporization such as LPG, two separate valves must be included one meter apart; the valve near the header or equipment must be a ¼-turn ball valve, and the valve on the terminal end must be a gate valve. In the case of a sampling tap, the arrangement must start downstream from the gate valve (purge).



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2.5 cm minimum

Ni

le

Machine to allow passage of the nipple

Valve

Weld nipple to pipe and then introduce sockolet and weld to pipe a nd nipple

Fig. 28. Sampling tap arrangement

The piston should pass through the coupling until it is flush with the inner wall of the pipe.

Feedthrough coupling into pipe supplied by valve manufacturer

Outlet for sampling arrangement

Fig. 29. Piston valve arrangement 8.1.2.17.5 Piping arrangements for sampling fluids with solids that entail a risk of plugging, such as the process service in sulfur plants, must include piston valves; see Fig. 29.

8.1.2.18 Pipin g arrangement f or steam sys tem



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8.1.2.18.1 Medium- and low-pressure steam systems must be designed with drain legs (condensate traps) and steam traps. The number, type and location of steam traps should be determined in detail engineering, and in at least the following cases:

a) b) c) d) e) f) g)

Upstream from the manually operated shutoff/isolation valves. Upstream from the pressure- and temperature-control valves. Upstream from the thermal expansion curves (loops); see Fig. 30. Upstream from an increase in elevation. At the end of the headers. Where condensate might accumulate. The case shown in Figure 30.

In the case of saturated steam piping where condensate may form due to the design and distances, drain legs must be installed.

Thermal expansion curves

Flow

Condensate trap

Fig. 30. Drain legs in expansion curv es 8.1.2.18.2 The condensate trap arrangement must conform to the typical arrangements shown in Figs. 31 and 32. The maximum separation between condensate traps in horizontal low-pressure steam piping must be 45 m, and 60 m for medium-pressure steam.



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SAME ∅ AS HEADER SAME ∅ AS HEADER

¾" TO TRAP

TYPE 1

¾" TO TRAP

Threaded end plug

Threaded end plug

(2" ∅ AND SMALLER WELDABLE INSERT)

"

"

TYPE 2 SAME ∅ AS HEADER

SAME ∅ AS HEADER ¾" TO TRAP

¾" TO TRAP

TYPE 4

TYPE 3 (3" HEADER WITH WELDABLE TEE)

¾" TO TRAP

¾" TO TRAP

TYPE 5

TYPE 6 (4” OR LARGER HEADER WITH INSERT)

Figure 31. Typical drain leg and steam trap arrangement 8.1.2.18.3 The steam trap arrangement must discharge into the condensate header and include a flanged steam trap with a drain and built-in filter, as well as a bypass, as shown in Fig. 33. [8.1.2.18.4 is missing in the original. –Editor]

8.1.2.18.5 Steam traps must comply with ASME PTC 39:2005 and ASTM F1139-88 or equivalents.



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Straight tee

Steam header

Steam flow Basic nipple arrangement

Collector

To steam trap Welded end plug

Two shutoff valves in class 600 lb and higher

Threaded end plug

Fig. 32. Typical condensate trap arrangements

Fig. 33. Steam trap arr angement



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8.1.2.18.6 Steam traps must be located so that they are accessible for safe operation and maintenance by personnel at finished floor level, without obstructing other installations and/or traffic in the area.

8.1.2.18.7. Piping branch lines and offshoots for steam distribution must be located in the top part of the headers or piping, preventing condensate entrainment and must have a manual shutoff valve (root valve) located as close as possible to the header without entrapping condensate.

8.1.2.18.8 Steam taps at service points must be DN 20 (NPS ¾). The terminal nipple must be made of ASTM A312/A312M-12 Type 304 or 316 or equivalent stainless steel.

8.1.2.19 Package equ ipm ent 8.1.2.19.1 Package equipment must be designed with flanged ends at the package boundary. 8.1.2.19.2 Piping and piping arrangements for package equipment must comply with this reference standard unless the Licensor indicates otherwise.

8.1.2.19.3 In package equipment, all supports, guides, directional stops, springs and hangers must be confined within the package equipment battery boundaries. The allowable forces and moments at the tiein points with the lines outside the package should not cause or transmit stress to the tied-in piping.

8.1.2.19.4 Package equipment piping must be secured during shipment to prevent damage to equipment and/or internal materials, and temporary elements to be removed after installation should be indicated in orange.

8.1.2.20 Filling station pipin g arrangements 8.1.2.20.1 Piping arrangements in loading islands must have sufficient space to allow access by personnel, and contention barriers on both ends of the island to protect the piping.

8.1.2.20.2 The height of the loading arm connection must be in keeping with the dimensions of the loading package system (tankers or tank trucks) and the fluid.

8.1.2.20.3 A utility station supplying air, water and stea m must be included and, when specified, breathing air.

8.1.2.20.4 The piping arrangements at islands for loading or unloading hydrocarbons or environmental pollutants must have a vapor return line to the vapor recovery system.

8.1.2.21 Piping arrangement for show ers and eye-wash stations Must be designed in unobstructed areas with easy access wherever hazardous chemicals are handled and personnel is exposed to splashing and/or spills, including areas where filters are cleaned. They must have a connection for transmitting these systems' operating signal.

8.1.2.22 Piping identification Piping must be identified per NRF-009-PEMEX-2004.

8.1.2.23 Anti corros ion pro tection



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8.1.2.23.1 All overhead carbon- and low- and intermediate-alloy steel piping must be protected with anticorrosion coatings complying with NRF-053-PEMEX-2006. For underground piping, coatings must comply with NRF-026-PEMEX-2008, with mechanical protection extending over the air/soil interface up to 50 cm above the finished floor le vel. This protection must withstand UV rays.

8.1.2.23.2 Galvanized piping coatings must comply with NRF-281-PEMEX-2012. 8.1.2.23.3 Metal piping with a thermal insulation system must have an anticorrosion coating complying with NACE SP0198:2010 or equivalent. This anticorrosion coating should only consist of primer, and should not have a finish coating.

8.1.3

Piping flexibili ty and suppo rts

8.1.3.1 Piping flexibil ity 8.1.3.1.1 Piping must be designed for a structural behavior that withstands the operating, design conditions and any special conditions to which it is subject, with the flexibility needed to control expansion and/or contraction, such as movements or displacements of supports, piping supports and equipment, without the piping undergoing excessive deformation that causes leaks, overstresses or failures, among other adverse effects, or inducing such effects in the facilities.

8.1.3.1.2 Piping must be designed and calculated per ASME B31.3:2010 to withstand pressure and temperature loads, environmental conditions (ice, hail), dynamic effects (impact, wind, earthquake, vibration and reaction forces), weight and fatigue, per ASME B31.3:2010, Paragraph 301, and combinations thereof.

8.1.3.1.3 To determine the resulting loads, the load cases indicated below and the combinations in Table 3 should be applied at a minimum:

a) b) c) d) e)

Operating loads Thermal loads Occasional loads (earthquake and wind, among others) Friction loads Test loads

MINIMUM LOADS TO BE ANALYZED CASE

TYPE

ALL OWABLE STRESS ( ASME B31.3:2010)

Temperature + Displacements

Thermal

SA

Weight + Pressure + Concentrated or external loads

Sustained

Sh

Temperature + Weight + Pressure + Load + Displacement

Operation

Paragraph 302.3.6

Wind or earthquake (whichever is greater)*

Occasional

Paragraph 302.3.6

Sustained + Occasional

Sustained

1.33 Sh

Hydrostatic Test

Sustained

1.33 Sh

*Submit both cases for review.



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SA: Range of allowable displacement stresses. Sh: Allowable stresses at operating temperature. Table 3. Minim um Loads 8.1.3.1.4 Occasional wind and earthquake loads should be determined by procedures given in the Civil Works Earthquake and Wind Design Manuals of the Federal Electricity Commission.

8.1.3.1.5 Valves, instruments and fittings should not be used as piping supports. 8.1.3.1.6 Piping that connects to reciprocating compressors or pumps must be designed to prevent the natural frequency of the system from a response to the excitation frequency of the equipment in various operating modes, applying the acoustic and mechanical methods needed to obtain the most efficient and lowest-cost design.

8.1.3.1.7 Flexibility studies should be performed using formal and informal methods. The formal method should be done with specialized software packages.

8.1.3.1.8 Piping should be classified according to the following criteria: A)

Category I, which must be analyzed with a formal method that should be detailed and performed on the piping in one or more of the following services or cases: a) Piping connected to dynamic equipment: DN 80 (NPS 2) and larger equipment connected to reciprocating pumps and compressors, centrifugal compressors and turbines whose normal operating temperature exceeds 90°C. Equipment connected to centrifugal pumps with the following characteristics: DN 100 to 250 (NPS 4 to 10) with normal operating temperatures of 145 °C or higher. DN 300 (NPS 12) and larger with normal operating temperatures of 120°C or higher. Piping with DN larger than that of the pump nozzle and normal operating temperatures of 120°C or higher. b) Piping connected to equipment with stress limitations, such as: air coolers, ejectors, heat exchangers, furnaces, boilers, steam generators, deaerators, pressure vessels, direct-fired heaters, process towers, spheres, storage tanks, flares and cold boxes, among others. c) Piping made of non-ferrous materials, such as titanium, Monel and Incoloy, among others. d) Piping in service with hazardous chemicals with a level 4 health risk per NOM-018-STPS2000. e) Piping with fluid in two phases (liquid and vapor). f) Piping under a vacuum (negative pressure). g) Jacketed piping. h) Transfer piping. i) Piping for venting systems and flares, including the discharge side of pressure relief valves. j) Piping DN 150 (NPS 6) and larger, with operating temperatures higher than 120°C. k) Piping DN 50 (NPS 2) and larger with operating temperatures higher than 250 °C. l) Piping of any DN (NPS) with metal design temperatures higher than 500°C. m) Piping with operating temperatures of ‒18°C (0°F) or lower. n) Piping DN 350 (NPS 14) and larger. o) Piping in bridges between offshore platforms. p) Piping located under the first deck of offshore platforms. q) Critical-service piping defined by the Licensor. r) Piping under severe cyclical conditions per ASME B31.3:2010. −

−

  

Standards Committee Petróleos Mexicanos and Subsidiaries s) t) u) v) w) B)


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Piping with expansion joints. Piping subject to temperature gradients (such as the banana effect). Piping connected to equipment where differential settling of 12 mm or more is expected. Piping designated as Category I in Fig. 34. The piping specified by PEMEX or the Licensor in the Service Specification.

Category II, which should be analyzed with informal methods (approximate methods or nondetailed computer programs): a) Piping connected to equipment with external load and/or stress limitations that would appear to be included in Category I, but is not, due to its diameter or temperature. b) All piping designated as Category II in Fig. 34.

C)

Category III, which should be analyzed using approximate methods. Calculation reports are not required. a) Piping not classified as Category I or II, operating at ambient temperature and up to DN 400 (NPS 16). b) Piping classified as Category III in Fig. 34.

8.1.3.1.9 Piping replacing existing piping that has operated successfully does not require a new analysis, provided there are no changes in diameter, geometry, location, supports, operating or design conditions, Piping Material Specifications, wall thickness or schedule.

8.1.3.1.10 When an accepted flexibility analysis is applied to identical, mirror and repetitive piping arrangements, an additional flexibility analysis is not required.



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HIGHER

CATEGORY I ) C ° (

E R U T A R E P M E T G N I T A R E P O

CATEGORY II

CATEGORY III

CATEGORY I

Lar er

NOMINAL PIPING DIAMETER Fig. 34. Piping Classifi cation by Category 8.1.3.1.11 The Contractor must deliver the calculation reports for the piping system studied, including reports using formal methods and those using informal methods. These reports should make it possible in and of themselves to identify the main data for the lines studied, and the analysis isometric must include information needed to review runs, such as the following:

a) b)

c)

Cover page showing: Project name and number, work site, plant, identification of line(s) studied. Analysis isometric showing: all essential information on the design and material quality; identification of the line(s); diameters; service fluid; operating pressures; operating temperature; insulation thickness, type and density; location; elevations; reference to key piping drawings; indication of continuity with other plans or isometrics; summary of calculated maximum forces and moments; resulting maximum stresses and allowable stresses, clearly indicating units used; points of interest (nodes); and type of supports, among others. Computer run output report (in the formal method) and/or results of the informal study, with essential information such as: line number(s); material of piping and connections; diameters; thicknesses; allowable stresses; calculated maximum stresses; modulus of elasticity; operating temperature and pressure; weights included in the calculation (pipe weight, thermal insulation, fluid and densities, among others); applied loads and load combinations (operating, wind and earthquake, among others); summary of forces and moments at the support points; compliance


d) e) f) g)


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check of forces and moments in nozzles; and all other information needed to revie w calculations. Schematic and /or copies of equipment connected. Summary with acceptance criteria and the name and signature of the individual responsible for the flexibility study. Summary of the study and acceptance criteria. Summary of critical loads on supports and at connection points.

PEMEX reserves the right to verify the designs prepared, and if at any time PEMEX finds that a design fails to comply with guidelines given in this reference standard, PEMEX may reject said design and require the Contractor to prepare new designs, at its expense, that do comply with said requirements.

8.1.3.1.12 The flexibility analysis studies must be applied to complete piping systems and when branch lines are involved, they must be part of the header, including supports and restrictions, up to the closest directional stop. All displacements that could occur in the piping system within the maximum operating temperature range must be included.

8.1.3.1.13 The piping configuration must have the flexibility needed to control thermal expansion and contraction through its direction changes, so that the resulting displacements and stresses remain within the allowable limits given in Table 3. If this is not possible, one or more of the following alternatives may be used:

a) b) c)

Expansion curves ("loops") Expansion joints, when specified by the licensor (under reserve and after approval by PEMEX) Mechanisms that allow angular, rotational or axial movement (after acceptance by PEMEX).

Expansion joints must comply with NRF-158-PEMEX-2012 or NRF-171-PEMEX-2007 and the following:

a) b)

They must not operate under torsion. They must not be of the slip-on or telescoping type.

8.1.3.2 Piping supports 8.1.3.2.1 The engineering must indicate the location and type of supports for all piping, which should be the result of the flexibility studies.

8.1.3.2.2 Piping supports must withstand the actions and combination of actions of the piping, including hydrostatic test loads, among others.

8.1.3.2.3 The piping arrangement must have the supports needed to ensure that connections do not transmit excessive stresses to the equipment while maintaining the alignment of the piping, which must be demonstrated by the Contractor in the applicable flexibility study.

8.1.2.3.4 Piping must have permanent supports. Temporary supports are only permitted for the hydrostatic test.

8.1.3.2.5 All supports must be made of material that withstands service and environmental conditions. Ductile and malleable cast iron is not permissible for piping supports.

8.1.3.2.6 Carbon-, low- and intermediate-alloy steel supports must be protected with anti-corrosion coatings that comply with NRF-053-PEMEX-2006.



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8.1.3.2.7 Piping supports must be located, supported or hung on structural elements. Supports on grating, anti-skid plates, railings, stairways or floors without concrete block s, among others, are not permissible.

8.1.3.2.8 Piping must not be supported on other piping. 8.1.3.2.9 Valves DN 450 (NNPS 18) and larger should preferably be supported by piping supports. 8.1.3.2.10 Flanges must not be used as piping supports. 8.1.3.2.11 Piping supports made of concrete, masonry or similar material must have an embedded plate or structural element protruding from the support, which must be the contact and slide surface between the piping and the piping support.

8.1.3.2.12 To the extent possible, piping welds should not be placed on support elements, wear plates or backing plates.

8.1.3.2.13 Sloped piping must have saddle-type supports, and elevation adjustments must be made in the saddle. The use of shims to adjust elevations is not permissible.

8.1.3.2.14 Piping supports must allow for installing valves, instruments and equipment without using temporary supports.

8.1.3.2.15 Wooden supports are not permissible. 8.1.3.2.16 Supports for piping with a thermal insulation system for cold service must be: a)

b)

High-density polyurethane with at least the following physical properties or materials with equivalent properties: 3 - Temperature range: ‒250°C to 100°C (‒418°F to 212°F); density: 240 kg/m - Compression strength: 795 kPA - Compression modulus of elasticity: 38.019 kPA ‒6 - Thermal expansion coefficient: ‒50 x 10 mm/mm-K - Thermal conductivity: 0.028 W/m-K and non-combustible Smooth metal casing with a vapor barrier that secures the arrangement as illustrated in Fig. 35. The casing plate may be galvanized carbon steel secured with ASTM A 307 bolts and A194 Gr 2H nuts, both galvanized or equivalent, per NRF-281-PEMX-2012.



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E = Insulation thickness Pipe Jacket

Metal finish of insulation High-density polyurethane

Reinforcement DN 350 (NPS 14) and larger

Free support Displacement ± 38 mm

Fig. 35. Supports for pi ping w ith a thermal insulation system 8.1.3.3 Backing plates 8.1.3.3.1 Support elements such as saddles, lugs, shoes, trunnions, fastening brackets, among others, must have a backing plate with alignment hole.

8.1.3.3.2 Backing plates must be made of material similar to and compatible with the piping material and have a thickness equivalent to that of the standard schedule for the piping to which it is welded for carbon-steel piping and the same or standard schedule, whichever is less, for non-ferrous materials.

8.1.3.4 Wear plates 8.1.3.4.1 When the project so specifies, carbon- and low- and intermediate-alloy steel piping with no insulation must have a wear plate between the piping and the support point on piping supports, which must be a 45°-120° angle segment of plate or pipe, per Table 4. DN (NPS) Angle in degrees 4 45 6 and larger 120 and use saddle The length of the wear plate must extend 10 cm on each side of the piping support.

Table 4. Wear Plates 8.1.3.4.2 Stainless steel, non-ferrous metal and non-metal piping should not rest directly on structural supports; there must be at least one wear plate.

8.1.3.4.3 Metal wear plates must be made of material similar to and compatible with the piping material and have a thickness of 6 mm (1/4”) for diameters up to DN 300 (NPS 12) and 10 mm (⅜”) for diameters of DN 350 (NPS 14) and larger; with complete peripheral welding and an alignment hole.

8.1.3.4.4 Non-metal wear plates and their adhesive should be selected on the basis of mechanical strength (crush and shear) and the temperature to which they are subject. They should also be resistant to the environment and have a service life at least equal to that specified for the piping.



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8.1.3.4.5 Wear plates must be of a length that they do not work out of the supports in service during temperature changes, vibrations or any other action, extending at least 100 mm on each end of the main supports or concrete support blocks.

8.1.3.4.6 The alignment holes in backing and wear plates must be 6 mm (¼”) in diameter and must be located at the lowest point and on an end that is accessible from outside the support. Alignment holes must not be obstructed by piping supports. The holes should be filled with epoxy resin that can withstand the operating temperature.

8.1.4

Service Index and Pipin g Material Specifi cations (PMS)

8.1.4.1 Requirements for Preparing the Service Index and Piping Material Specifications 8.1.4.1.1 The Service Index should be prepared on Form 12.1.1 and the Piping Material Specifications on Form 12.1.3 in Annex 12.1 of this reference standard.

8.1.4.1.2 The Contractor must prepare the Service Index for the piping included in the scope of the project and, if applicable, the Piping Material Specifications for service or components not covered by this reference standard, and the Contractor must request approval by authorized PE MEX personnel.

8.1.4.1.3 The Contractor must ensure that the Piping Material Specifications for the project comply with this reference standard and if technical discrepancies are found, the Contractor must submit a written request to PEMEX to determine the appropriate definition.

8.1.4.1.4 For particular cases in which PEMEX specifies in the project that steam piping for power generation must be designed per ASME B31.1:2010 or equivalent, the Contractor must prepare the Piping Material Specification based on that standard and the applicable requirements of this reference standard.

8.1.4.1.5 In the selection of Piping Material Specifications from this reference standard and/or preparation of standards for the project, the Contractor must identify, as applicable, shall verify and review the service, Class, work center environment, design and operating conditions, NDT and other factors including, but not limited to:

a) b) c) d) e) f) g) h) i) k) l)

Chemical composition and/or concentration of the substance. Classification and hazard levels of the substance. Content of abrasive solids or any other foreign substances. Contamination of the substance by the piping. Corrosion tolerance. Service life, maintenance, wear and/or corrosion of the piping. Mechanical integrity and confinement of the substance by the piping. Results of materials used and experience gained. Environmental conditions. Constructability. Cost-benefit ratio

8.1.4.2 Technologist’ s or Licensor’s Piping Material Specifications 8.1.4.2.1 The process Piping Material Specifications must be agreed upon between PEMEX and the Licensor or Technologist and will be used in the piping engineering. The Piping Material Specifications for the utilities and firefighting water systems must be as given in this reference standard unless PEMEX



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indicates in the Service Specification that the Technologist’s or Licensor's Piping Material Specifications should be used.

8.1.4.2.2 In projects where no Technologist’s or Licensor’s Piping Material Specifications are given, the Contractor is responsible for selecting specifications from this reference standard per 8.1.4.1.

8.1.4.3 Nomenclature for Piping Material Specific ations The nomenclature for identifying the process and service piping specifications is as follows:

a)

The first character defines: C = Offshore facilities T = Facilities at onshore industrial plants

b)

The second character defines the Class, as follows: A = Class 150 B = Class 300 D = Class 600 E = Class 900 F = Class 1500 G = Class 2500

c)

The third character is a consecutive number consisting of two digits. This character indicates the consecutive number of the Piping Material Specification within each Class by base material. It begins with 01 and progressively increases. If applicable, the Technologist’s or Licensor's Piping Material Specifications should begin with 30 and the Contractor's with 60.

d)

The fourth character defines the base material and consists of the letter T and a number, as indicated below: T 1 = Carbon steel T 2 = Low- and intermediate-alloy steel T 3 = Stainless steel T 4 = Nickel and nickel alloys T 5 = Titanium and titanium alloys T 6 = Aluminum and aluminum alloys T 7 = Tantalum, tantalum alloys and other non-ferrous alloys T 8 = Non-metal materials TX = Materials other than the above

e)

Examples: C-A01T1 = Offshore industrial facilities (C); Class 150 (A); Specification one (01); Material Carbon steel (T1). T-B01T3 = Facilities at onshore industrial plants (T); Class 300 (B); Specification one (01); Material - Stainless steel (T3). C-A31T1 = Offshore industrial facilities (C); Class 150 (A); Licensor's specification one (31); Material - Carbon steel (T1). T-B61T3 = Facilities at onshore industrial plants (T); Class 300 (B); Contractor's or vendor's specification one (61); Material = stainless steel (T 3).


8.2


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Inform ation to be prov ided by PEMEX

8.2.1 PEMEX will provide Bidders/Contractors with any special Service Specification (SS) for each project.

8.2.2 The Service Specification will be the compendium of the minimum information needed to award a contract for the Contractor's piping engineering services, which must comply with this reference standard.

8.2.3 The Service Specification must contain at least the following information or, as the case may be, specify whether the Contractor's scope includes developing or obtaining said information, as appropriate and applicable to the project.

a) b)

l)

Scope of the project. Information on the work center or location for which the piping is intended, such as a geographic location schematic of the facility, highwa ys and distance from the closest city or town. Weather conditions at the work center or project site, with data for at least the last five years on maximum, minimum and 30-day average temperatures; maximum, dominant and prevailing winds and wind directions; earthquake zone; rainfall; environmental conditions (marine environment, fumes that attack metal, such as ammonium and sulfur); and corrosive environments due to sulfates, nitrates or hydrosulfuric acid that are to be taken into account. List any available drawings of underground and surface facilities and major adjacent structures at the project site, as applicable. Special technical specifications of the project, when applicable. General plant layout drawing. Piping and instrumentation schematics, as applicable Process flow schematics, as applicable. Piping index (line index), as applicable. Piping Material Specification index and Piping Material Specifications for the project, as applicable, including: - Technologist’s or Licensor’s Piping Material Specifications, if applicable. - The Piping Material Specifications and any special requirements to use non-metal piping and/or piping with grooved ends, among others. List of tie-ins between new and existing piping and type of connection, with location references and schematics, as applicable. Required piping service life.

8.3

Information to be provid ed by the Contractor

c)

d) e) f) g) h) i) j)

k)

8.3.1 The Contractor must prepare and deliver to PEMEX the documentation listed below for the piping engineering included in the scope of services as required by this reference standard and the Service Specification.

8.3.2 The catalogs, installation, operation and maintenance manuals and the results of software runs, among others, which, due to their validity characteristics, should not and/or cannot be altered with a translation into Spanish, are permitted in English or, alternatively, in the original language accompanied by a certified technical translation into Spanish per Annex 12.2, Paragraph 7, of this reference standard. The Spanish translation will be used for the purposes of acceptance and the outcome, as well as the fabrication and/or construction of the piping and pip ing systems.



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8.3.3 The documents must comply with NOM-008-SCFI-2002 ("General System of Units of Measurement." In exceptional cases, foreign contractors may use their system of units of m easurement in parentheses, preceded by equivalents per NOM-008-SCFI-2002, which shall be the basis for acceptance with respect to the law, guarantees and claims, among others, as well as the fabrication and construction of the piping.

8.3.4. The review, confirmation or acceptance of the documents by PEMEX or the party it designates or omission to do so shall not release the Contractor from its responsibility for guaranteeing and achieving full compliance with this reference standard and the Service Specification, and the Contractor shall remain obligated to correct any deviations, omissions, errors, misinterpretations, defects or hidden flaws, among others, to the satisfaction of PEMEX.

8.3.5 The Contractor must prepare and submit at least the documents listed in the following subparagraphs to PEMEX for review (each of which must be duly identified) with the following information at a minimum:

a) b) c) d) e) f) g) h) i) j) k) l) m)

Contractor's name and logos Project name PEMEX contract number Document title Document identification number Revision number Description of revision Revision date Piping or line nomenclature Symbols Name and signature of Contractor's engineer responsible for engineering Name and signature of the individual responsible for the Contractor's quality management Table of contents, including page numbers

8.3.5.1 Design bases. 8.3.5.2 Piping Index (Line Index) 8.3.5.3 Service Index and Piping Material Specifications 8.3.5.4 Overhead and buried piping drawings, as applicable a) b) c) d)

General equipment layout drawing (updated) Area key plans Plan view by area Elevation, cross-section and detail drawings

8.3.5.5 Index of isometrics and isometrics of piping DN 50 (NPS 2) and larger (unless otherwise indicated in the project) for all project piping materials. These must indicate all the essential information on design, materials and for fabrication, containing at least: piping number; Piping Materials Specification; list of materials; diameters; substance handled; design, operating and test pressures (including type of test); design and operating temperature; thermal insulation system and thickness; heat treatment (if applicable); percentage of X-ray and other nondestructive tests that should be performed; dimensions; elevations; location; location and identification of supports; reference to piping drawing; P&ID; and continuation in other isometrics.



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8.3.5.6 Calculation reports for: a) b) c) d)

Flexibility study on piping per 8.1.3.1.11 of this reference standard. Thickness of piping not included in the Piping Material Specifications in this reference standard and for any new or additional Piping Material Specifications developed by the Contractor. Blind plates larger than DN 600 (NPS 24). Tie-ins and construction details (if applicable).

8.3.5.7 Specification, drawings and t ypical installation arrangements for piping supports. 8.3.5.8 List and details of tie-ins. 8.3.5.9 Materials list for piping and valve components and, if applicable, the requisition and purchase order as specified in the Service Specification and Contract.

8.3.5.10 Specification of piping components, including special specifications such as: piping supports, expansion joints and vibration dampers, among others, and if applicable, the requisition and purchase order as required by the Service Specification and Contract.

8.3.5.11 If applicable, the opinion and report from the audit on the engineering and related piping documents as regards industrial safety and environmental protection or sim ilar requirements, prepared by an independent professional expert recognized by the Mexican Department of Energy through the National Hydrocarbons Commission, complying with the Enactment Act on Article 27 of the Constitution for the Petroleum Industry and Related Regulations.

8.3.5.12 An intelligent 3-D Electronic Model per NRF-107-PEMEX-2010, if specified in the Service Specification.

8.3.5.13 Any additional documentation indicated in the Service Specification. 8.4.5.14 Any additional documentation indicated in the Contract. 8.3.6 The Contractor must deliver the final piping engineering documents indicated in 8.3 to PEMEX as part of the project book, as approved for construction or as approved for a given phase of the project revision, signed by the responsible engineer and approved by the individual responsible for quality assurance.

8.3.7 The documents and project book must be delivered in an original hard copy and in an electronic file in the format of the original source in which they were created, and in as many reproducible copies as indicated by PEMEX in the Service Specification.

8.3.8 The approved-for-construction versions of the engineering documents and Piping Material Specifications must not include notes, annotations or directions that indicate "approximate dimensions," "adjust in the field," "check, modify and adjust in the field," "by the contractor or vendor," "by the buyer," "by a third party," among others.

8.3.9 The piping must be identified in compliance with the P&ID’s and applicable nomenclature in the Piping Material Specifications.

8.3.10 The project books must comply with NRF-271-PEMEX-2011, providing the following information in the following order:

a)

Section A1



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- Service specifications (SS) - Design bases - Special technical standards and specifications

b)

Section A2 - General location drawing - Process flow schematics - Piping and instrumentation schematics - Piping index (line index) - Service index for process and utility piping - Project Piping Material Specification - Underground installation schematics, if any

c)

Section A3 - Project schematics - Key piping schematic and section views - Detail piping schematic (plant, elevation and cross-sectional views) - Piping isometrics - Final piping index (line index) - Final service index (process and service piping) - List and location of battery boundary connections - List of materials and volumetrics and, if applicable, purchase orders - List of supports and typical support drawings. - List and specification of special supports and, if applicable, the purchase order - Calculation reports - List and specification of special piping fittings, such as expansion joints and, if applicable, purchase orders - 2-D Electronic Models/3-D Electronic Models, if within the scope of services contracted - Technical annexes.

d)

Section D Constructability procedures

e)

Section G Opinion and report from the audit on the engineering and related piping documents as regards industrial safety and environmental protection or similar requirements under the Enactment Act on Article 27 of the Constitution for the Petroleum Industry and Related Regulations, as applicable.

f)

Section H Administrative, technical and legal documents written during the project, inclu ding documentation accrediting the professional expert and authorizing the responsible engineer, legal representative and individual in charge of quality assurance for the Contractor, as applicable.

8.4

Accept ance criteria

8.4.1 The Contractor must have a Quality Management System certified per LFMN, the scope of which includes the field of application and scope of this reference standard, in accordance with NMX-CC-9001IMNC-2008 (ISO 9001:2008), applying N MX-CC-9004-IMNC-2009 (ISO 9004:2009).



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8.4.2 The Contractor must prepare and deliver the Quality Plan for the project to PEMEX, which must expressly comply with NMX-CC-10005-IMNC-2006 (ISO 10005:2005) in order to confirm compliance with this reference standard, the Service Specification and the Co ntract, and include the following:

a)

Autonomy and clear separation of the responsibilities of the individual in charge of quality and inspection for the Contractor.

b)

Review of the Service Specification and contract in order to ensure that it contains the information required by this reference standard and that the Contractor may proceed with the services and work in terms of the contract.

c)

Preparation of an execution schedule containing the critical path, verification or inspection and payment events, and a mitigation and recovery plan in the event of deviations.

d)

Preparation of the verification or inspection plan listing events to be verified, reviewed or witnessed by PEMEX or its designated agent.

e)

Assurance that the personnel is qualified or certified, as applicable, and will remain so for the duration of the project for the task, activity, process, examination or test which they are to conduct, following an approved and proven procedure or practice, keeping and maintaining a record of all activities and personnel involved.

f)

Assurance that all processes, tasks, activities or work have at least one verification or inspection point before continuing.

g)

Assurance that the Conformances or Non-Conformances are written up, recorded and reported upon each verification or inspection.

h)

Assurance that all actions needed to resolve all Non-Conformances, both those found by the individual in charge of quality assurance for the Contractor and those found by PEMEX or its designated agent, are taken and completed.

i)

Comply with the LFMN, its regulations and the legal provisions arising therefrom.

j)

k)

Assurance that preparation of the project book begins with the signing of the contract and that the information and history documents are added as they are written, up to the delivery and acceptance of the piping engineering by PEMEX and winding down of the Contract. In addition, one copy of the project book must be retained for at least five years from the final settlement of the Contract. Assurance that the engineering documents are reviewed and endorsed with the signature and professional I.D. of the responsible engineer and the individual in charge of quality assurance for the Contractor.

8.4.3. The Conformance or Non-Conformance Reports must record the results of all evaluations and the required data or values needed for comparison purposes and determination of compliance with this Reference Standard, the Service Specification and the contract. The Contractor must deliver the original copies of the Conformance or Non-Conformance Reports to PEMEX, including reports, opinions or certifications, which must comply with the LFMN and related Regulations.

8.4.4 The Contractor must deliver the piping engineering indicated in the Service Specification and/or Contract to PEMEX, completely finished in due time and form, complying with thi s reference standard and free of any Non-Conformances.



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8.4.5 The work and services contracted by PEMEX that are subject to this reference standard must be verified by the individual in charge of quality assurance for the Contractor independently of the verification and/inspection by PEMEX or its designated agent.

8.4.6 The individual in charge of quality assurance for the Contractor must verify at least the following in documentary form and, if applicable, physically:

a) b) c) d) e)

Compliance with the contract, Service Specification and applicable standards. Execution schedule and progress reports. Verification (inspection) plan. Acknowledgement of the technical competence and reliability of the accredited individuals and independent experts involved in the work. Competence and qualifications of personnel involved in and performing the work.

8.4.7 Verification or inspection by PEMEX or its designated agent shall not release the Contractor from liability for guaranteeing and achieving full compliance with this reference standard, the contract or the Service Specification, and the Contractor shall remain obligated to correct any deviations, omissions, errors, misinterpretations, defects or hidden flaws, among others.

8.4.8 The Contractor must at all times provide and facilitate free access to the facilities where the wok and services are performed for PEMEX and/or its designated agent, and access to all contract-related documentation.

8.4.9 The individual in charge of quality assurance for the Contractor must verify and confirm that the accreditation of the accredited individuals is currently valid and complies with the LFNM, furnishing PEMEX with evidence thereof.

8.4.10. The services covered by this reference standard are subject to review and verification by PEMEX or whomever it designates at all times in order to comply with this reference standard, the Service Specification and Contract for at least level IV in accordance with NRF-049-PEMEX-2009, and until all verifications determine and demonstrate their conformance.

9.

RESPONSIBILITIES

9.1

PEMEX

9.1.1 9.2.

To ensure compliance with this reference standard. Contractors

9.2.1

To comply with this reference standard.

9.2.2 To request any clarification from or report any omission or discrepancy to PEMEX in writing during the bidding phase and before commencing activities and/or services. To advise PEMEX of technical problems and request their solution if it finds any obvious error in the Piping Material Specifications that could result in risks.

9.2.3 To deliver piping engineering in conformance with this reference standard and current applicable laws and regulations.

9.2.4 To deliver the engineering to PEMEX signed and endorsed by its responsible engineer and quality assurance representative, and with the approval of the independent professional expert, if applicable.



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9.2.5 The Contractor shall be technically and legally liable for the piping engineering covered by the scope of its services.

10.

ADAPTATION TO MEXICAN OR INTERNATIONAL STANDARDS

This reference standard adopts ISO 15649:2001 for onshore facilities and ISO 13703:2000 with ISO 13703:2000/Cor. 1:2002 for offshore facilities, with the definition between parties and special requirements of PEMEX contained in Section 8 of this reference standard.


11.


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BIBLIOGRAPHY

11.1. API RP 520 part II-2003 (R2011) . Sizing, Selection, and Installation of Pressure-Relieving Devices in Refineries—Part II, Installation.

11.2. API RP 551-1993 (R2007) . Process Measurement Instrumentation 11.3. API RP 615-2010. Valve Selection Guide 11.4. API RP 751-2007. Safe Operation of Hydrofluoric Acid Alkilation Units – Third Edition 11.5. API RP 934-A-2008 with adenda 1-201.0 Materials and Fabrication of 2 1/4Cr-1Mo, 2 1/4Cr-1Mo1/4V, 3Cr-1Mo, and 3Cr-1Mo-1/4V Steel Heavy Wall Pressure Vessels for High-temperature, Highpressure Hydrogen Service.

11.6. API RP 934-C-2011. Materials and Fabrication of 1-1/4Cr-1/2Mo Steel Heavy Wall Pressure Vessels for High Pressure H ydrogen Service Operating at or Below 825°F (441°C).

11.7. API RP 941-2008. Steels for Hydrogen Service at Elevated Temperatures and Pressures in Petroleum Refineries and Petrochemical Plants

11.8. API RP 945-2003 R2008 Avoiding Environmental Cracking in Amine Units. 11.9. API RP 1102-2007. Steel Pipelines Crossing Railroads and Highways 11.10. API RP 2201-2003 (R2010). Safe Hot Tapping Practices in the Petroleum & Petrochemical Industries

11.11. API Spec 6D-2008 errata 1-2008, errata 2-2008, errata 3-2009, errata 4-2010, errata 5-2010, errata 6-2011, adenda 1-2009 y adenda 2-2011, Specification for Pipeline Valves - ISO 14313:2007 (Identical), Petroleum and natural gas industries—Pipeline transportation systems— Pipeline valves.

11.12. API Spec 6FA-1999 (R2006) Errata 1-2006 y Errata 2-2008, Specification for Fire T est for Valves 11.13. API Spec 15LE: 2008. Polyethylene (PE) Line Pipe 11.14. API Std 594:2010. Check Valves: Flanged, Lug, W afer and Butt-welding 11.15. API Std 598:2009. Valve Inspection and Testing 11.16. API Std 599-2007. Metal Plug Valves-Flanged, Threaded and Welding Ends 11.17. API Std 600-2009 and Errata 1-2009. Steel Gate Valves—Flanged and Butt-welding Ends, Bolted Bonnets

11.18. API Std 602-2009. Steel Gate, Globe, and Check Valves for Sizes NPS 4 (DN 100) and Smaller for the Petroleum and Natural Gas Industries

11.19. API Std 607-2010 Fire Test for Quarter-turn Valves and Valves Eq uipped with Nonmetallic Seats



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11.20. API Std 608-2008. Metal Ball Valves—Flanged, Threaded and Butt-Welding E nds 11.21. API Std 609-2009. Butterfly Valves - Double-flanged, Lug- and W afer-type 11.22. ASME Seccti on VIII Divi sion 1-2010 and ad enda 2011 with errata 2012, Rules for Construction of Pressure Vessels

11.23. ASME A13.1-2007. Scheme for the Identification of Piping Systems 11.24. ASME B1.1-2003 (R2009). Unified Inch Screw Threads (UN and UNR Thread Form) 11.25. ASME B1.20.1-1983 (R2006). Taper Pipe Thread Dimensions 11.26. ASME B1.20.2M-2006. Pipe Threads, 60 deg, General Purpose (Inch) 11.27. ASME B16.5-2009. Pipe Flanges and Flanged Fittings 11.28. ASME B16.9-2007. Factory-Made Wrougth Buttwelding Fittings 11.29. ASME B16.11-2009. Forged Fittings, Socket-Welding and Threaded 11.30. ASME B16.20-2007, Metallic Gaskets for Pipe Flanges Ring-Joint, Sp iral-Wound, and Jacketed 11.31. ASME B16.21-11, Nonmetallic flat gaskets for pipe flanges 11.32. ASME B16.25-2007. Buttwelding Ends 11.33. ASME B16.34-2009 with Sup lement 2010. Valves-Flanged, Threaded, And Welding End 11.34. ASME B16.47-2011. Large Diameter Steel Flanges NPS 26 Through NPS 60 11.35. ASME B16.48-2010. Line Blanks 11.36. ASME B31.1-2010. Power Piping 11.37. ASME B31.4-2009, Pipeline Transportation Systems for Liquid H ydrocarbons and Other Liquids 11.38. ASME B31.8-2010, Gas Transmission and Distribution Piping Systems 11.39. ASME B31.3-2010. Process Piping 11.40. ASME B36.10M-2004 (R2010). Welded and Seamless Wrought Steel Pipe 11.41. ASME B36.19M-2004 (R2010). Stainless Steel Pipe 11.42. ASME PTC 39-2005 Steam Traps 11.43. ASTM A36/A36M-08. Standard Specification for Carbon Structural Steel 11.44. ASTM A47/A 47M-99 (R2009). Standard Specification for Ferritic Malleable Iron Castings 11.45. ASTM A53/A53M-12. Standard Specification for Pipe, Steel, Black and Hot-Dipped, Zinc-Coated, Welded and Seamless



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11.46. ASTM A90/A90M-11. Standard Test Method for Weight [Mass] of Coating on Iron and Steel Articles with Zinc or Zinc-Alloy Coatings 11.47. ASTM A105/A 105M-11a Standard Specification for Carbon Steel Forgings for Piping Applications 11.48. ASTM A106/A106M-11. Standard Specification for Seamless Carbon Steel Pipe for HighTemperature Service

11.49. ASTM A134/A 134-96 (R2005), Standard Specification for Pipe, Steel, Electric-Fusion (Arc)Welded (Sizes NPS 16 and Over)

11.50. ASTM A123/A123M-09. Standard Specification for Zinc (Hot-Dip Galvanized) Coatings on Iron and Steel Products

11.51. ASTM A153/A153M-09. Standard Specification for Zinc Coating (Hot-Dip) on Iron and Steel Hardware

11.52. ASTM A182/A182M-11a. Standard Specification for Forged or Rolled Alloy and Stainless Steel Pipe Flanges, Forged Fittings, and Va lves and Parts for High-Temperature Service

11.53. ASTM A193/A193M-12. Standard Specification for Alloy-Steel and Stainless Steel Bolting Materials for High Temperature or High Pressure Service and Other Special Purpose Applications

11.54. ASTM A194/A194M-11. Standard Specification for Carbon and Alloy Steel Nuts for Bolts for High Pressure or High Temperature Service, or Both

11.55. ASTM A216/A 216M-08. Standard Specification for Steel Castings, Carbon, Suitable for Fusion Welding, for High- Temperature Service

11.56. ASTM A217/A217M-11. Standard Specification for Steel Castings, Martensitic Stainless and Alloy, for Pressure-Containing Parts, Suitable for High-Temperature Service

11.57. ASTM A 234/A 234M-11a, Standard Specification for Piping Fittings of Wrought Carbon Steel and Alloy Steel for Moderate and High Temperature Service

11.58. ASTM A240/A240M-12. Standard Specification for Chromium and Chromium-Nickel Stainless Steel Plate, Sheet, and Strip for Pressure Vessels and for General Applications

11.59. ASTM A276-10, Standard Specification for Stainless Steel Bars and Shapes 11.60. ASTM A307-10. Standard Specification for Carbon Steel Bolts and Studs, 60 000 PSI Tensile Strength

11.61. ASTM A312/A312M-12. Standard Specification for Seamless, Welded, and Heavily Cold Worked Austenitic Stainless Steel Pipes

11.62. ASTM A320/A320M-11a. Standard Specification for Alloy-Steel and Stainless Steel Bolting Materials for Low-Temperature Service

11.63. ASTM A322-07, Standard Specification for Steel Bars, Alloy, Standard Grades



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11.64. ASTM A333/A333M-11. Standard Specification for Seamless and Welded Steel Pipe for LowTemperature Service

11.65. ASTM A335/A335M-11. Standard Specification for Seamless Ferritic Alloy-Steel Pipe for HighTemperature Service

11.66. ASTM A351/A351M-12. Standard Specification for Castings, Austenitic, for Pressure-Containing Parts

11.67. ASTM A352/A352M-06(R2012). Standard Specification for Steel Castings, Ferritic and Martensitic, for Pressure-Containing Parts, Suitable for Low- Temperature Service

11.68. ASTM A358/A 358M-08a . Standard Specification for Electric-Fusion-Welded Austenitic ChromiumNickel Stainless Steel Pipe for High-Temperature Service and General Applications

11.69. ASTM A387/A387M-11. Standard Specification for Pressure Vessel Plates, Alloy Steel, Chromium-Molybdenum

11.70. ASTM A395/A 395M (R2009). Standard Specification for Ferritic Ductile Iron Pressure-Retaining Castings for Use at Elevated T emperatures

11.71. ASTM A536-2009 Standard Specification for Ductile Iron Castings 11.72. ASTM A403/A403M-11. Standard Specification for Wrought Austenitic Stainless Steel Piping Fittings

11.73. ASTM A409/A409M-09. Standard Specification for Welded Large Diameter Austenitic Steel Pipe for Corrosive or High-Temperature Service

11.74. ASTM A420/A420M-10a. Standard Specification for Piping Fittings of Wrought Carbon Steel and Alloy Steel for Low-Temperature Service

11.75. ASTM A436-84 (R2011). Standard Specification for Austenitic Gray Iron Castings 11.76. ASTM A439-83 (R2009). Standard Specification for Austenitic Ductile Iron Castings 11.77. ASTM A494/A 494M-09e1-2010. Standard Specification for Castings, Nickel and Nickel Alloy 11.78. ASTM A515/A 515M-10 , Standard Specification for Pressure Vessel Plates, Carbon Steel, for Intermediate- and Higher-Temperature Service

11.79. ASTM A563M-07a. Standard Specification for Carbon and Alloy Steel Nuts 11.80. ASTM A587-96 (R2005). Standard Specification for Electric-Resistance-Welded Low-Carbon Steel Pipe for the Chemical Industry

11.81. ASTM A671/A 671-10. Standard Specification for Electric-Fusion-Welded Steel Pipe for Atmospheric and Lower Temperatures 11.82. ASTM A672/A672-09. Standard Specification for Electric-Fusion-Welded Steel Pipe for HighPressure Service at Moderate Temperatures



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11.83. ASTM A778-01 (R2009 e1-2009). Standard Specification for Welded Unannealed Austenitic Stainless Steel Tubular Products

11.84. ASTM B62-09, Standard Specification for Composition Bronze or Ounce Metal Castings 11.85. ASTM B88M-09. Standard Specification for Seamless Copper Water Tube 11.86. ASTM B127-05 (R2009). Standard Specification for Nickel-Copper Alloy (UNS N04400) Plate, Sheet, and Strip

11.87. ASTM B165-05 (R2009). Standard Specification for Nickel-Copper Alloy (UNS N04400)* Seamless Pipe and Tube

11.88. ASTM B166-11. Standard Specification for Nickel-Chromium-Iron Alloys (UNS N06600, N06601, N06603, N06690, N06693, N06025, and N06045)* and Nickel-Chromium-Cobalt-Molybdenum Alloy (UNS N06617) Rod, Bar, and Wire

11.89. ASTM B177/B 177M-11. Standard Guide for Engineering Chromium Electroplating 11.90. ASTM B265-11. Standard Specification for Titanium and Titanium Alloy Strip, Sheet, and Plate 11.91. ASTM B283/B 283-12. Standard Specification for Copper and Copper-Alloy Die Forgings (HotPressed)

11.92. ASTM B363-06a. Standard Specification for Seamless and Welded Unalloyed Titanium and Titanium Alloy Welding Fittings

11.93. ASTM B366-10a, Standard Specification for Factory-Made Wrought Nickel and Nickel Alloy Fittings

11.94. ASTM B367-09. Standard Specification for Titanium and Titanium Alloy Castings 11.95. ASTM B381-10e1-2011. Standard Specification for Titanium and Titanium Allo y Forgings 11.96. ASTM B521-98 (R2004). Standard Specification for Tantalum and Tantalum Alloy Seamless and Welded Tubes

11.97. ASTM B564-11. Standard Specification for Nickel Alloy Forgings 11.98. ASTM B619-10e1-2012. Standard Specification for Welded Nickel and Nickel-Cobalt Alloy Pipe 11.99. ASTM B650-95 (R2008). Standard Specification for Electrodeposited Engineering Chromium Coatings on Ferrous Substrates

11.100. ASTM B708-05. Standard Specification for Tantalum and Tantalum Allo y Plate, Sheet, and Strip 11.101. ASTM B733-04 (R2009). Standard Specification for Autocatalytic (Electroless) NickelPhosphorus Coatings on Metal

11.102. ASTM B841-99 (R2010). Standard Specification for Electrodeposited Coatings of Zinc Nickel Alloy Deposits

11.103. ASTM B861-2010. Standard Specification for Titanium and Titanium Alloy Seamless Pipe



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11.104. ASTM B928/B928M-09. Standard Specification for High Magnesium Aluminum-Alloy Sheet and Plate for Marine Service and Similar Environments

11.105. ASTM C585-10. Standard Practice for Inner and Outer Diameters of Thermal Insulation for Nominal Sizes of Pipe and Tubing

11.106. ASTM C656-07. Standard Specification for Structural Insulating Board, Calcium Silicate 11.107. ASTM C1423–98 (R2011). Standard Guide for Selecting Jacketing Materials for Thermal Insulation

11.108. ASTM C1729–12. Standard Specification for Aluminum Jacketing for Insulation 11.109. ASTM D1599-99 (R2011). Standard Test Method for Resistance to Short-Time Hydraulic Pressure of Plastic Pipe, Tubing, and Fittings

11.110. ASTM D2000-12. Standard Classification System for Rubber Products in Automotive Applications)

11.111. ASTM D2105-01 (R2007)e1. Standard Test Method for Longitudinal Tensile Properties of “Fiberglass” (Glass-Fiber-Reinforced Thermosetting-Resin) Pipe and Tube

11.112. ASTM D2310-06. Standard Classification for Machine-Made “Fiberglass” (Glass-Fiber-Reinforced Thermosetting-Resin) Pipe

11.113. ASTM D2321-11, Standard Practice for Underground Installation of Thermoplastic Pipe for Sewers and Other Gravity-Flow Applications

11.114. ASTM D2412-11. Standard Test Method for Determination of External Loading Characteristics of Plastic Pipe by Parallel-Plate Loading

11.115. ASTM D2774-12, Standard Practice for Underground Installation of Thermoplastic Pressure Piping

11.116. ASTM D2992-11, Standard Practice for Obtaining Hydrostatic or Pressure Design Basis for “Fiberglass” (Glass-Fiber-Reinforced Thermosetting-Resin) Pipe and Fittings

11.117. ASTM D2996-01 (R2007)e1-2007. Standard Specification for Filament-Wound "Fiberglass" (Glass-Fiber-Reinforced Thermosetting-Resin) Pipe

11.118. ASTM D3035–10 Standard Specification for Polyethylene (PE) Plastic Pipe (DR-PR) Based on Controlled Outside Diameter

11.119. ASTM D3350-12. Standard Specification for Polyethylene Plastics Pipe and Fittings Materials 11.120. ASTM D4024-05. Standard Specification for Machine Made "Fiberglass" (Glass-Fiber-Reinforced Thermosetting Resin) Flanges

11.121. ASTM D4101-11, Standard Specification for Polypropylene Injection and Extrusion Materials 11.122. ASTM D5685-11, Standard Specification for “Fiberglass” (Glass-Fiber-Reinforced ThermosettingResin) Pressure Pipe Fittings



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11.123. ASTM F468M-06 (R2012). Standard Specification for Nonferrous Bolts, Hex Cap Screws, and Studs for General Use (Metric)

11.124. ASTM F714–12. Standard Specification for Polyethylene (PE) Plastic Pipe (SDR-PR) Based on Outside Diameter

11.125. ASTM F1055–11. Standard Specification for Electrofusion Type Polyethylene Fittings for Outside Diameter Controlled Polyethylene Pipe and Tubing

11.126. ASTM F1139-88 (R2010) Standard Specification for Steam Traps and Drains 11.127. ASTM F 1290–98a (R2011). Standard Practice for Electrofusion Joining Polyolefin Pipe and Fittings

11.128. ASTM F1476-07. Standard Specification for Performance of Gasketed Mechanical Couplings for Use in Piping Applications

11.129. ASTM F2389-10, Standard Specification for Pressure-rated Polypropylene (PP) Piping S ystems 11.130. ASTM F2619/F 2619M-11, Standard Specification for High-Density Polyethylene (PE) Line Pipe 11.131. AWS A5.13/A5.13M:2010 Specification for Surfacing Electrodes for Shielded Metal Arc Welding 11.132. AWS A5.21/A5.21M:2011 Specification for Bare Electrodes and Rods for Surfacing 11.133. AWWA C 901-2008. Polyethylene (PE) Pressure Pipe and Tubing, 1/2 in. (13 mm) Through 3 in. (76 mm), for Water Service

11.134. AWWA C906-2007. Polyethylene (PE) Pressure Pipe and Fittings, 4 in. (100 mm) Through 63 in. (1,600 mm), for Water Distribution and Transmission

11.135. BS 6364:1984. Specification for valves for cryogenic service 11.136. BS EN 1057:2006. Copper and copper alloys. Seamless, round copper tubes for water and gas in sanitary and heating applications

11.137. CGA-G7-2008 Compressed Air for Human Respiration 11.138. CGA-G7.1-2011Commodity Specification for Air 11.139. CSN EN 1555-3-2010, Plastics piping systems for the supply of gaseous fuels - Polyethylene (PE) - Part 3: Fittings

11.140. CSN EN 12201-3 - Plastics piping systems for water supply, and for drainage and sewerage under pressure - Polyethylene (PE) - Part 3: Fittings

11.141. DIN EN 1982: 2008. Copper and copper alloys - Ingots and castings 11.142. DIN 17455-1999. Welded circular stainless steel tubes with general quality requirements Technical delivery conditions



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11.143. DIN 86019:2006. Seamless tubes made of CuNi10Fe1.6Mn for pipes - Dimensions for standard and precision tubes

11.144. EEMUA Publication No.144-1987, Specification: Tubes Seamless and Welded 11.145. EEMUA Publication No.145-1987, Specification: Flanges Composite and solid 11.146. EEMUA Publication No.146-1987, Specification: Fittings 11.147. FM Approval Class Number 1613-2006. Approval Standard for Polyethylene (PE) Pipe and Fittings for Underground Fire Protection

11.148. FM Ap pprovals Class Number 1614-2008. Fiber Reinforced Composite (FRC) Pipe and Fittings for Underground Fire Protection Systems

11.149. MSS SP-44-2010 E2011. Steel Pipeline Flanges 11.150. MSS SP-75-2008. Specification for High-Test, Wrought, Butt-Welding Fittings 11.151. MSS SP-80-2008. Bronze Gate, Globe, Angle and Check Valves 11.152. MSS SP-95-2006 Swage (D) Nipples and Bull Plugs 11.153. MSS SP-97-2012. Integrally Reinforced Forged Branch Outlet Fittings-Socket Welding, Threaded, and Buttwelding Ends

11.154. NACE 37519-1985. Corrosion Data Survey - Metal Section 11.155. NACE MR0103:2010. Materials Resistant to Sulfide Stress Cracking in Corrosive Petroleum Refining Environments

11.156. NACE RP0170:2004. Protection of Austenitic Stainless Steels and other Austenitic Alloys from Polythionic Acid Stress Corrosion Cracking During Shutdown of Refinery Equipment

11.157. NACE 5A171:2007. Materials for Receiving Handling and Storing Hydrofluoric Acid 11.158. NACE SP0198-2010 Control of Corrosion Under Thermal Insulation and Fireproofing Materials— A Systems Approach

11.159. NACE SP0403:2008 Avoiding Caustic Stress Corrosion Cracking of Carbon Steel Refinery Equipment and Piping.

11.160. NACE SP0472:2010. Methods and Controls to Prevent In-Service Environmental Cracking of Carbon Steel Weldments in Corrosive Petroleum Refining Environments

11.161. NSF/ANSI 61-2009. Drinking Water System Components - Health Effects



12.

ANNEXES

12.1

Annex 1. Forms

Form 12.1.1 Service in dex Piping Material Services Design condit ions Specification Temp. Pressure

Heat Treat. and Stress Relief

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X-ray/ Nondestructive testing

Corrosion tolerance mm (in)

Class Face Material

PAGE 1/N Form 12.1.2 Index of Piping Material Specifications

Specificati on

Service

X-ray of circumf. butt-welded joints

Class, Face, Materials3

Heat Treat. and Stress Relief

Corrosion Tolerance

Service operating limits 2

Pressure and temp. limits by range of flange class (ASME B16.5) 1

PAGE 1/N

General Notes to Piping Material Specifications 1

Even when foreign standards referenced in this annex are not literally followed by the words "or equivalent," this requirement must be met as part of each and every specification contained in this reference standard. 2

The operating limits shown are the most common in the oil industry. The Contractor is responsible for checking and reviewing service fluid conditions for which Piping Material Specifications are used in the specific project to ensure that they are the appropriate concentration, pressure, temperature, material specification and corrosion tolerance conditions in accordance with the Piping Material Specification gi ven in this annex. 3

The information given in the column with the heading “heat treatment” is separate from the manufacturing process required by the piping and its components according to manufacturing processes based on material specifications in the ASTM designation or equivalent, such as: normalizing, thermal stabilization, grain size, and equivalent carbon and impact tests, among others. See Paragraph 8.1.1.5 (Heat Treating).



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Form 12.1.3 Piping Material Specifications Material Specific ations for Piping

Facilities Service

Pressure and temp. limit s Allowable corrosion

Material: Heat treat. and stress relief

Component

Piping Pipe Nipples Nipple Conc. swage Eccen. swage Connections 90° elbow 45° elbow Straight tee Reducing tee Coupling Reducing coupling End plug Solid-bar plug Street elbow 90° long-radius elbow 45° elbow Straight tee Reducing tee Concentric reducer Eccentric reducer Cap plug

Notes

Diameter (DN (NPS)

Min. thickness (in.) or schedule/Class

Nomenclature RT

NDT

Class 150

Valve internals Trim: Ends

Description


Integrally reinforced connections

Threadolet or equivalent Sockolet or equivalent Latrolet or equivalent Weldolet Nipolet or nipple pipet Flanges Socket weld end flanges Weld neck flanges Blind flanges Blind flanges Orifice plate flanges Long-neck flange Valves Gate valves Gate valves Gate valves Globe valves Globe valves Check valves Check valves Check valves Gaskets Gaskets Hardware Bolts Nuts Misc. Figure eights (one-piece) Figure eights (separate blind and spacer) Tee type filters Tee type filters


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Connections for branch lines

Notes:

Graphic C-A01T1 Connections for branch lines

) S R E E H T C E N I M N I A I D S N R O E I D S A N E E H M I D

Straight tee, threaded ends Reducing tee, threaded Threadolet Straight tee with g rooved ends Reducing tee with grooved ends This specification prohibits making dir ect or lap weld branch connections.

(

BRANCH LINE DIAMETER (DIMENSIONS IN INCHES) PAGE 2 / N


12.2


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Annex 2. Index of offs hore Pipin g Material Specifi cations (PMS)

Specification 5

C-A01T1

C-A02T1

C-A03T1

C-A04T1

Service

Cement and barite Fuel gas Instrument gas Residual gas Diesel Heating oil Oily open drainage Venting

Material

Class & face type

Corrosion tolerance

150

1.6 mm

RF

(0.0625 in)

150

1.6 mm

Carbon steel

Carbon steel RF

(0.0625 in)

150

1.6 mm

RF

(0.0625 in)

150

1.6 mm

Carbon steel

Carbon steel RF

C-A05T1

Plant air Potable water

150 Carbon steel RF

C-A06T1

C-A07T1

C-A08T1

C-A09T1

C-A10T1

Sour gas Hydrocarbon mixture (gas/liquid) Venting Chemical drain Diethanolamine (rich)

Carbon steel with requirements of ISO 15156 & API RP 945

Oily water (sour)

Carbon steel with requirements of ISO 15156

Low-pressure condensates Poor diethanolamine Oil Pressurized oily drain

Salt water

(0.0625 in) CS + Galv. 0.0 mm (0.0 in) CS 1.6 mm (0.0625)

150

3.2 mm

RF

(0.125 in)

150

3.2 mm

RF

(0.125 in)

150

3.2 mm

RF

(0.125 in)

150

3.2 mm

RF

(0.125 in)

150

6.3 mm

RF

(0.250 in)

Carbon steel

Carbon steel Carbon steel with requirements of ISO 15156 + galvanized

Pressure & temp. limits 2

X-ray welded join ts, %

Heat treat. and stress relief 3

1.8 MPa 96° C

N/A

NO

1.17 MPa 260° C

20

NO

1.17 MPa 260° C

10

NO

1.96 MPa 38° C

20

Note 1.6 of the PMS

1.38 MPa 70°C

5

NO

1.80 MPa 93° C

20

YES

1.80 MPa 93° C

10

YES

1.48 MPa 176° C

20

NO

1.48 MPa 176° C

10

NO

1.58 MPa 150° C

33

YES



Specification 5

Service

Material Material

C-A11T1

Firefighting water (overhead) Service seawater Crude washing water Backwashing water Brine

Carbon steel + galvanized

C-A01T3

C-A02T3

C-A03T3 C-A04T3 C-A05T3

C-A01T4

C-A02T4 C-A01T7

C-A01T8

Oxygen scavenger Corrosion inhibitor Incrustation inhibitor Anti-foam solution Polymer solution Deemulsifier

Instrument air Recovered salt water pH regulator (95% sulfuric acid, 69-85% phosphoric acid, 28% hydrochloric acid) Organic biocide Bactericide solution Firefighting seawater Service water, potable water, hot water and treated seawater (Service for living quarter platforms only)

Class & face type

Corrosion tolerance

150

6.3 mm

RF

(0.250 in)

316L Stainless Steel

150

0.0 mm

RF

(0.0 in)


150

0.0 mm

RF

(0.0 in)

316L Stainless Steel 316L Stainless Steel 316L Stainless Steel

150

0.0 mm

RF 150

(0.0 in) 0.0 mm

RF 150

(0.0 in) 0.0 mm

RF

(0.0 in)

Nickel-Mo-Cr Alloy (Ni-Mo-Cr)

150

0.0 mm

RF

(0.0 in)

Nickel-Mo-Cr Alloy (Ni-Mo-Cr) Copper-nickel alloy (Cu-Ni)

150

0.0 mm

Fiberglass and epoxy resin (RTRP)

RF 150

(0.0 in) 0.0 mm

FF

(0.0 in)

150

0.0 mm

FF

(0.0 in)

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X-ray welded join jo in ts, ts , %


1.55 MPa 38° C

5

NO

1.79 MPa 93° C

33

NO

1.79 MPa @ 93° C

20

NO

1.79 MPa 93° C

10

NO

1.03 MPa 54° C

5

NO

1.02 MPa 60° C

33

NO

1.83 MPa 43° C

50

NO

1.83 MPa 43° C

33

NO

1.55 MPa 37° C

5

NO

1.24 MPa 65° C

N/A

N/A


Specification 5

C-B01T1

C-B02T1

C-B03T1

C-B01T3

C-B02T3

C-D01T1

C-D02T1

Service

Fuel gas Residual gas Diethylene glycol High-pressure condensates Poor diethanolamine Oil Sour gas Hydrocarbon mix (gas/liquid) Recovered condensates Chemical drain Oil Oily water Diethanolamine (rich) Oxygen scavenger Corrosion inhibitor Incrustation inhibitor Anti-foam solution


Material Material

Class & face type

Corrosion tolerance

300

1.6 mm

Carbon steel RF

(0.0625 in)

300

3.2 mm

RF

(0.125 in)

300

3.2 mm

RF

(0.125 in)

300

0.0 mm

RF

(0.0 in)

300

0.0 mm

RF

(0.0 in)

600

1.6 mm

RF

(0.0625 in)

600

3.2 mm

RF

(0.125 in)

Carbon steel


316L stainless steel 316 L Stainless Steel

Fuel gas Residual gas Recovered condensates Dry diethylene glycol Diethylene glycol Poor diethanolamine

Carbon steel

Residual gas (sour) Sour gas Hydrocarbon mix (gas/liquid) Wet diethylene glycol Wet diethylene glycol Chemical drain Rich Diethanolamine Oil Oily water


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4.69 MPa 93° C

20

Heat treat. and stress relief 3 YES Table 330.1.1 and Table 331.1.1 ASME B31.3 B31.3

YES 4.52 MPa 149° C

20

Table 330.1.1 and Table 331.1.1 ASME B31.3 B31.3

YES Table 330.1.1 and Table 331.1.1 ASME B31.3 B31.3

4.52 MPa 149° C

20

5.03 MPa 138° C

33

NO

5.03 MPa 138° C

20

NO

YES 9.38 MPa 60° C

33


YES 9.20 MPa 121° C

33



Specification 5

C-D03T1

C-D01T3

C-E01T1

C-E02T1

C-E01T3

C-E02T3

C-F01T1

Service

High-pressure condensates Poor diethanolamine Oil High-pressure venting Corrosion inhibitor Hydraulic oil Seal oil for LP compressors Lubricating oil Suction gas for injection into wells Well injection water


Material Material


600

3.2 mm

RF

(0.125 in)

600

0.0 mm

RF

(0.0 in)

900

3.2 mm

RJ

(0.125 in)

900

3.2 mm

Carbon steel

Carbon steel

Lubricating oil Seal oil


Well injection gas Well injection water

Corrosion tolerance

Carbon steel

Hydrocarbon mix Recovered oil

Salt water for injection into wells (without corrosion inhibitor)

Class & face type

Super duplex stainless steel (25Cr-8Ni3Mo)

RJ

(0.125 in)

900

0.0 mm

RJ

(0.0 in)

900

0.0 mm

RJ

(0.0 in)

1500

3.2 mm

RJ

(0.125 in)

Carbon steel

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Heat treat. and stress relief 3 YES Table 330.1.1 and Table 331.1.1 ASME B31.3 B31.3

9.20 MPa 121° C

33

9.48 MPa 149° C

33

NO

14.03 MPa 93° C

50

NO

YES

13.32 MPa 168° C

50

14.41 MPa @ 93° C

50

NO

10.78 MPa 60° C

50

NO

23.40 MPa 93° C


YES 100


Notes for: Index to Offshore Piping Material Specifications (PMS) 1

Even when foreign standards referenced in this annex are not literally followed by the words "or equivalent," this requirement must be met as part of each and every specification contained in this reference standard. 2

The operating limits shown are the most common in the oil industry. The Contractor is responsible for checking and reviewing service fluid conditions for which the Piping Material Specifications are used in the specific project to ensure that they are the appropriate concentration, pressure, temperature, material specification and corrosion tolerance conditions in accordance with the Piping Material Specification gi ven in this annex.



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3

The information given in the column with the heading “Heat Treatment” is separate from the manufacturing process required by the piping and its components according to manufacturing processes based on material specifications in ASTM designation or equivalent, such as: normalizing, thermal stabilization, grain size, and equivalent carbon and impact tests, among others. See Paragraph 8.1.1.5 (Heat Treating). 4

These Piping Material Specifications are also applicable to Pem ex Exploración y Producción’s onshore facilities.

5

To see each of the Piping Material Specifications listed, refer to the annex attached to this reference standard with links to specifications. When a Piping Material Specification indicates two or more valves of the same type, for example, a gate valve with design NRF-211-PEMEX-2008, ISO 10434:2004 or ASME B16.34:2009 or equivalent, the supplier or contractor must ask the user (PEMEX) which type valve should be specified on the basic data sheets according to the basic design engineering for the project.



12.3

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Annex 3. Index of onshor e Piping Material Specifi cations (PMS)

Specification5

T-A01T1

Service Fresh water Cooling water Raw water Pretreated water Treated water Service water Chilled water

X-ray buttwelded Heat treat. Class, face, circumferential and stress materials joints, % relief 3

Corrosion tolerance

Service Operating limits2

N/A

1.6 mm (0.063 in)

1961 kPa @ 38°C Temp. range (‒20 to 50°C)

1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

N/A

1.6 mm (0.063 in)

1378 kPa @ 100°C Temp. range (-20 to 100°C)

1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

N/A

1.6 mm (0.063 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

N/A

1.6 mm (0.063 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

(Class 150) 5

RF CS

(Class 150)

T-A02T1

T-A03T1

T-A04T1

Anhydrous ammonium Aniline Fuel or sweet gas Liquid benzene Toluene Inert gas Butane Ethane (gas) Regeneration gas Natural gas Non-corrosive hydrocarbons H 2 CO2 Methane (gas) Isopropyl alcohol N-propyl alcohol Cyclohexane Non-corrosive hydrocarbon condensate Crude oil Reduced crude Hydrocarbon condensate Non-corrosive hydrocarbons Non-corrosive light hydrocarbons Isopropyl alcohol Methanol Light naphthas Heavy naphthas Non-corrosive chemical reagents Water non-corrosive hydrocarbons Air- non-corrosive hydrocarbons - water Corrosion inhibitor Contaminated condensate (waterhydrocarbons)

50

RF CS (Class 150)

33

RF CS

(Class 150) 20

RF CS

Pressure & temperature limits by range of flange class (ASME B16.5)1



Specification5

T-A05T1

T-A06T1

T-A07T1

Service High-vacuum residual Light alkylate Heavy alkylate Asphalts Fuel oil Kerosene Diesel Heavy gasoil Fuel oil Heating or thermal oil Flushing oil Recovered oil Oily water Anti-foam agent Chemical deemulsifier Glycol Flushing water (without H 2S, NH 3 ) Reflux water (recirculating) Compressor or blower discharge combustion air Plant air Sour gas (partial H 2 S pressure over 0.05 psia)

T-A08T1

Sour water

T-A09T1

Rich amine/poor amine

T-A10T1

Liquid sulfur (jacketed)

T-A11T1

Sulfur plant process, Sulfur vapor

X-ray butt-welded Heat treat. Class, face, circumferential and stress materials joints, % relief 3

NRF-032-PEMEX-2012

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Corrosion tolerance


N/A

1.6 mm (0.063 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

N/A

1.6 mm (0.063 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

3.2 mm (0.125 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

3.12 mm (0.125 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

3.12 mm (0.125 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

N/A

1.6 mm (0.063 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

N/A

3.2 mm (0.125 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

(Class 150) 10

RF CS

(Class 150) 5

RF CS

(Class 150) 33

33

20

33

33

Stress relief NACE

RF Killed carbon MR0103:2010 steel (Class 150) Stress relief RF NACE Killed carbon MR0103:2010 steel (Class 150) Stress relief RF API RP 945 Killed carbon 2003. steel (Class 150) RF CS (Class 150) RF CS




Specification5

T-A12T1

Service Wet venting Liquid drain (non-corrosive hydrocarbons)


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Corrosion tolerance


1.6 mm (0.063 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

3.2 mm (0.125 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

5 mm (0.200 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

1373 kPa @ 38°C Temp. range (-20 to 60°C) 1569 kPa @ 38°C Temp. range (-20 to 200°C) 1373 kPa @ 38°C Temp. range (-20 to 50°C) 1961 kPa @ 38°C Temp. range (-20 to 350°C)

1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

5.0 mm (0.200 in)


1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C

1.6 mm (0.063 in)


1980 kPa @ -29 to 38°C 1172 kPa @ 260°C 758 kPa @ 371°C 344 kPa @ 482°C

1.6 mm (0.063 in)


1.6 mm (0.063 in)


1980 kPa @ -29 to 38°C 1172 kPa @ 260°C 552 kPa @ 426°C 344 kPa @ 482°C 1980 kPa @ -29 to 38°C 1172 kPa @ 260°C 552 kPa @ 426°C 344 kPa @ 482°C

(Class 150) 20

RF CS

N/A

(Class 150)

T-A13T1

Sour gas venting Acid gas venting

T-A14T1

50% caustic soda Alkaline solution (KOH)

T-A15T1

Firefighting water (Fresh water)

Instrument air, shower and eye Note 4 Applies washing station air

T-A16T1

T-A17T1

95% or higher sulfuric acid

T-A18T1

Low-pressure steam (.448 MPa) Steam condensate

20

50

Stress relief NACE

RF Killed carbon MR0103:2010 steel (Class 150) Stress relief RF NACE Killed carbon SP0403:2008 steel (Class 150)

5

N/A

1.6 mm (0.063 in)

N/A

0.0 mm (0.0 in)

N/A

3.2 mm (0.125 in)

N/A

1.6 mm (0.063 in)

RF(CS) (Class 150) 5

50

RF Galv. CS (Class 150) RF CS (Class 150)

5

RF CS


1961 kPa @ -28 to 38°C

1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 1961 kPa @ -28 to 38°C 1172 kPa @ 260°C 7758 kPa @ 371°C

(Class 150)

T-A19T1 Acid gas

T-A01T2

Regeneration products

T-A02T2

Decoking, residual, non-corrosive hydrocarbons

T-A03T2 Asphalt 1, asphalt 2

33

100

20

10

Stress relief RF NACE Killed carbon SP0472-2010 steel YES Table 330.1.1 (Class 150) and Table RF 331.1.1 (1¼Cr-½Mo) ASME B31.3 or equivalent YES (Class 150) Table 330.1.1 and Table RF 331.1.1 (5Cr-½Mo) ASME B31.3 YES (Class 150) Table 330.1.1 and Table RF 331.1.1 (5Cr- ½ Mo) ASME B31.3



Specification 5

T-A04T2

Services

Service: Topped crude oil, reduced crude oil, HV residual

Hot venting T-A05T2 Closed liquid drain (non-corrosive hydrocarbons) Methane (gas) Ethane (gas) Propane T-A01T3 Butane Note 4 Applies Ethylene Methanol Non-corrosive hydrocarbons Methane Ethane Ethylene T-A02T3 Propane Methanol Non-corrosive hydrocarbons

T-A03T3

T-A04T3

Dry venting (cold) Non-corrosive hydrocarbons Closed liquid drain (cold) Rich/poor amine

Instrument air, Breathing air, seal air, Note 4 Applies compressor and blower suction air

T-A05T3

T-A06T3

Phosphates

T-A07T3

Reduced crude Hydrocarbons Reduced residual Lubricating and seal oil


NRF-032-PEMEX-2012

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Corrosion tolerance

YES

100

(Class 150) Table 330.1.1 3.2 mm and Table RF (0.125 in) 331.1.1 9Cr-1Mo ASME B31.3 YES

100

(Class 150) Table 330.1.1 1.6 mm and Table RF (0.063 in) 331.1.1 9Cr-1Mo ASME B31.3

20

(Class 150) RF 304 Type SS

20


20


20


5


33


20





1980 kPa @ -29 to 38 °C 1172 kPa @ 260°C 552 kPa @ 426°C 344 kPa @ 482°C




N/A

0 mm (0 in)


N/A

0 mm (0 in)


1896 kPa @ -190 to 38°C 1172 kPa @ 260°C 551 kPa @ 426°C

N/A

0 mm (0 in)


1896 kPa @ -190 to 38°C 1172 kPa @ 260°C 551 kPa @ 426°C

N/A

0 mm (0 in)



N/A

0 mm (0 in)


N/A

0 mm (0 in)



N/A

0 mm (0 in)



1896 kPa @ -29 to 38 °C 1172 kPa @ 260°C



Specification5

T-A08T3

Services

Demineralized water (for demineralization units upstream from deaerator)

T-A09T3 Acetaldehyde

T-A10T3

Gas to burner Process gas Spent gas (All three gases are refinery products.)

T-A11T3

Combustion gases

T-A01T4

Hydrocarbons + water

Methane (gas) Ethane (gas) Propane T-A02T4 Butane Note 4 applies Ethylene Methanol Non-corrosive hydrocarbons

T-A01T8

Potable water Note 4 applies (underground)

T-A02T8

Firefighting water Note 4 Applies (underground)

X-ray buttwelded circumferential joints, %

Class, face, materials

5


50

(Class 150) RF 316L Type SS

NRF-032-PEMEX-2012

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PAGE 93 OF 104



Corrosion tolerance


N/A

0 mm (0 in)


1896 kPa @-29 to 38°C 1172 kPa @ 260°C 551 kPa @ 426°C 344 kPa @ 482°C

N/A

0 mm (0 in)



20

(Class 150) RF 316L Type SS

N/A

0 mm (0 in)



20


YES and thermal stabil.

0 mm (0 in)



20

(Class 150) RF Ni-Cu Alloy

N/A

0 mm (0 in)


2000 kPa @-29 to 38°C 600 kPa @ 400°C 100 kPa @ 538°C

20

(Class 150) RF ASTMA A-333 Gr. 3

N/A

1.6 mm (0.063 in)


1961 kPa @ -50 to 38 °C 1172 kPa @ 260°C

N/A

0 mm (0 in)

1177 kPa @ 41°C (4 to 50°C)

PER PROJECT AND MANUFACTURER

N/A

0 mm (0 in)

1370 kPa @ 23°C

PER PROJECT AND MANUFACTURER

N/A

N/A

(Class 150) FF Polypropylene (Random copolymer) (Class 150) RF HDPE (High-density polyethylene)



Specification5

Services

Firefighting water T-A03T8 (underground) Note 4 applies Water to cationic and anionic units

T-A04T8

Potable water

Note 4 applies (underground)

T-A05T8

Potable water

Note 4 applies (underground)

T-B01T1 Anhydrous

ammonium

T-B02T1

Liquid benzene Phosphate Nitrogen


N/A

N/A

N/A

50

33

(Class 150) FF RTRP (Glass-fiberreinforced thermosetting resin pipe) (Class 150) FF HDPE (High-density polyethylene) (Class 150) FF RTRP (Glass-fiberreinforced thermosetting resin pipe) (Class 300) RF CS (Class 300) RF CS

N/A

N/A

N/A

NRF-032-PEMEX-2012

Rev: 0

PAGE 94 OF 104

Corrosion tolerance

0 mm (0 in)

0 mm (0 in)

0 mm (0 in)

N/A

1.6 mm (0.063 in)

N/A

1.6 mm (0.063 in)


1370 kPa @ 90°C

Pressure & temperature limits by range of flange class (ASME B16.5)1 PER PROJECT AND MANUFACTURER 1370 kPa @ 90°C

1370 kPa @ 23°C

PER PROJECT AND MANUFACTURER 1370 kPa @ 23°C

1550 kPa @ 37°C

PER PROJECT AND MANUFACTURER 1550 kPa @ 37°C

4680kPa @100°C 5102 kPa @-28 to 38°C 4171 kPa @ 260°C Temp. range 3481 kPa @ 399°C (-20 to 100°C) 5102 kPa @ 38°C Temp. range (-20 to 350°C)

5102 kPa @-28 to 38°C 4171 kPa @ 260°C 3481 kPa @ 399°C



Specification5

Services

T-B03T1

Butane Ethane Natural gas LPG Fuel gas Sweet gas Methane Propane Cyclohexane Condensates of noncorrosive hydrocarbons Reduced crude Non-corrosive hydrocarbons Methanol Light naphthas Heavy naphthas Water + noncorrosive hydrocarbons Fuel oil Heating or thermal oil Flushing water Recovered oil Anti-foam agent

T-B04T1

Medium-pressure steam (1.896 MPa) Medium-pressure condensate

T-B05T1

Sour gas (partial H 2 S pressure over 0.05 psia)

T-B01T2

Hydrocarbons + Hydrogen Regeneration products Catalyst Air + carbon dioxide + water


NRF-032-PEMEX-2012

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PAGE 95 OF 104


Corrosion tolerance


N/A

1.6 mm (0.063 in)


5102 kPa @-28 to 38°C 4171 kPa @ 260°C 3481 kPa @ 399°C

N/A

1.6 mm (0.063 in)


5102 kPa @-28 to 38°C 4171 kPa @ 260°C 3481 kPa @ 399°C

3.2 mm (0.125 in)


5102 kPa @-28 to 38°C 4171 kPa @ 260°C 3481 kPa @ 399°C

5170kPa @38°C Temp. range (-20 to 475°C)


20

(Class 300) RF CS

20

(Class 300) RF CS

33

(Class 300) RF Killed CS

100

(Class 300) Table 330.1.1 1.6 mm and Table RF (0.063 in) 331.1.1 (1¼Cr-½Mo)

Stress relief NACE MR0103:2010

YES

ASME B31.3



Specification5

T-B02T2

Services Asphalt Solvent asphalt Heavy gasoil Residual Hydrocarbons Butane-air-steam mix Steam-nitrogen Butadiene


NRF-032-PEMEX-2012

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Corrosion tolerance

YES





(Class 300) Table 330.1.1 3.2 mm and Table Ring Joint (0.125 in) 331.1.1 (1¼Cr-½Mo)



20

(Class 300) RF 304 TYPE SS

N/A

0 mm (0 in)

4119 @ 38°C Temp. range (-50 to 100°C)

4964 kPa @ -190 to 38°C 3206 kPa @ 260°C 2792 kPa @ 426°C

20


N/A

0 mm (0 in)

4119 @ 38°C Temp. range (-190 to 100°C)

4964 kPa @ -190 to 38°C 3206 kPa @ 260°C 2792 kPa @ 426°C

N/A

0 mm (0 in)


N/A

0 mm (0 in)

N/A

0 mm (0 in)

4120 kPa @ 50°C Temp. range (-20 to 50°C) 4119 kPa @ 38°C Temp. range (-20 to 520°C) 4119 kPa @ 38°C Temp. range (-20 to 520°C)

100

(Class 300) Table 330.1.1 1.6 mm and Table RF (0.063 in) 331.1.1 5Cr - ½Mo ASME B31.3

YES

T-B03T2

Residual, HV residual

100

(Class 300) Table 330.1.1 3.2 mm and Table RF (0.125 in) 331.1.1 9Cr - 1Mo ASME B31.3

Hydrocarbons + H 2 Hydrogen Hydrocarbons + T-B04T2 Hydrogen + hydrosulfuric acid (H2 S) Hydrocarbons Methane Ethane Propane T-B01T3 Butane Note 4 Applies Pentane Methanol Non-corrosive hydrocarbons Methane Ethane T-B02T3 Propane Methanol Non-corrosive hydrocarbons

T-B03T3

Toluene and TBC

T-B04T3

Vacuum residual Seal oil

T-B05T3 Air plus catalyst Catalysis



YES

100

ASME B31.3

33

20

20

(Class 300) RF 304 TYPE SS (Class 300) RF 304 TYPE SS (Class 300) RF 316H TYPE SS

4964 kPa @-29 to 38°C 3206 kPa @ 260°C 2792 kPa @ 426°C 2447 kPa @ 538°C 4964 kPa @-29 to 38°C 3309 kPa @ 260°C 2895 kPa @ 426°C 2516 kPa @ 538°C



Specification5

Services

Methane Ethane Propane T-B01T4 Butane Note 4 Applies Pentane Methanol Non-corrosive hydrocarbons Natural gas LPG Fuel gas Methane Ethane Propane Butane T-D01T1 Sweet gas Fuel gas Heavy naphthas Light naphthas Condensates Non-corrosive hydrocarbons Methanol Nitrogen

T-D02T1

Sour gas (partial H 2 S pressure over 0.05 psia)


T-D04T1

20

(Class 300) RF ASTMA A333 Gr. 3

1.6 mm (0.063 in)


5102 kPa @-50 to 38°C 4171 kPa @ 260°C

33

(Class 600) Table 330.1.1 1.6 mm and Table RF (0.063 in) 331.1.1 CS


10204 kPa @ -29 to 38°C 8308 kPa @ 260°C 6998 kPa @ 399°C

(Class 600) Stress relief RF NACE Killed carbon MR0103:2010 steel

3.12 mm (0.125 in)


10204 kPa @ -29 to 38°C 8308 kPa @ 260°C 6998 kPa @ 399°C

3.2 mm (0.125 in)


10204 kPa @ -29 to 38°C 8308 kPa @ 260°C 6998 kPa @ 399°C

1.6 mm (0.063 in)


10204 kPa @ -29 to 38°C 8308 kPa @ 260°C 6998 kPa @ 399°C

(Class 600) Table 330.1.1 1.6 mm and Table RF (0.063 in) 331.1.1 1¼ Cr - ½ Mo





N/A

YES

ASME B31.3

33

Stress relief NACE

Poor amine Rich amine

33

(Class 600) MR0103:2010 RF Stress relief Killed carbon API RP 945 steel 2003 or equivalent (Class 600) RF CS

N/A YES

T-D01T2

Hydrocarbons

100

ASME B31.3

T-D02T2

Gas and oil vapor Oil Hydrocarbons and water



33

Medium-pressure steam (1.896 MPa) Water to boilers

Rev: 0

PAGE 97 OF 104

Corrosion tolerance

Sour water

T-D03T1

NRF-032-PEMEX-2012

YES

100

(Class 600) Table 330.1.1 3.2 mm and Table RF (0.125 in) 331.1.1 9Cr - 1Mo ASME B31.3



Specification5

Services

Methane Ethane Propane T-D01T3 Butane Note 4 applies Methanol Non-corrosive hydrocarbons

T-D02T3

Methane Ethane Propane Methanol Non-corrosive hydrocarbons

T-D03T3

Hydrocarbons Methanol Seal oil DEA at temperatures exceeding 80°C

T-D04T3

Hydrocarbons plus water

Methane Ethane Propane T-D01T4 Butane Note 4 applies Methanol Non-corrosive hydrocarbons

T-E01T1

Medium-highpressure steam (5.86 MPa) Water to boiler

T-E02T1

Inert gas Non-corrosive hydrocarbons


NRF-032-PEMEX-2012

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PAGE 98 OF 104


Corrosion tolerance


N/A

0 mm (0 in)


9928 kPa @-29 to 38°C 6412 kPa @ 260°C 5584 kPa @ 426°C

N/A

0 mm (0 in)


9928 kPa @-29 to 38°C 6412 kPa @ 260°C 5584 kPa @ 426°C


9928 kPa @ -29 to 38 °C 6412 kPa @ 260°C 5584 kPa @ 426°C



10204 kPa @ -50 to 38°C 8308 kPa @ 260°C

33


33


33


N/A

0 mm (0 in)

33

(Class 600) RF 347H TYPE SS

YES At min. temp of 1093°C and thermal stabilization

0 mm (0 in)

33

See (Class 600) Table 330.1.1 RF 1.6 mm and Table ASTMA A(0.063 in) 331.1.1 333 Gr. 3 ASME B31.3


50

(Class 900) YES Weldable Table 330.1.1 ends 1.6 mm and Table Killed carbon (0.063 in) 331.1.1 steel ASME B31.3


50

(Class 900) YES Ring Joint Table 330.1.1 1.6 mm and Table (RJ) (0.063 in) 331.1.1 Killed carbon ASME B31.3 steel


FLANGES NOT PERMISSIBLE LIMITED TO: 8826 kPa @ -29°C TO 371°C

LIMITED TO: 8826 kPa @ -29°C TO 371°C



Specification5

Services

T-E01T2

Superheated highmedium pressure steam (5.86 MPa)

T-E02T2

Hydrocarbons + hydrogen + hydrosulfuric acid

T-F01T1

High-pressure steam (9.997 MPa) Steam condensate Water to boiler

T-F02T1

Inert gas Hydrogen + nitrogen

T-F01T2

T-F02T2

Superheated high pressure steam

Startup hydrogen


100

100

100

100

100

100

NRF-032-PEMEX-2012

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PAGE 99 OF 104

Corrosion tolerance

YES (Class 900) Table 330.1.1 Weldable 1.6 mm and Table ends (0.063 in) 331.1.1 1¼Cr ½Mo ASME B31.3

(Class 900) Ring Joint (RJ) 1¼Cr-½Mo Class 1500 Weldable ends Killed carbon steel Class 1500 Ring joint (RJ) Killed carbon steel Class 1500 Weldable ends 1¼C ½Mo


Pressure & temperature limits by range of flange class (ASME B16.5)1 FLANGES NOT PERMISSIBLE


15513 kPa @ -29 °C to 38°C 9307 kPa @ 482°C

1.6 mm (0.063 in)


15513 kPa @-29 to 38°C 13755 kPa @ 260°C 9307 kPa @ 482°C

YES Table 330.1.1 and Table 331.1.1 ASME B31.3

1.6 mm (0.063 in)


FLANGES NOT PERMISSIBLE 18305 kPa @ -29 °C to 38°C 14710 kPa @ 371°C


1.6 mm (0.063 in)


LIMITED TO: 18305 kPa @ -29 °C to 38°C 14710 kPa @ 371°C

1.6 mm (0.063 in)


1.6 mm (0.063 in)



YES Table 330.1.1 and Table 331.1.1 ASME B31.3 YES Class 1500 Table 330.1.1 and Table Ring joint 331.1.1 (RJ) ASME B31.3 1¼Cr-½Mo and API RP 941-2008

FLANGES NOT PERMISSIBLE 15478 kPa @ 482°C

25855 kPa @ 38°C 15478 kPa @ 482°C

Notes to: Piping Material Specifications for o nshore industrial plants 1

Even when foreign standards referenced in this annex are not literally followed by the words "or equivalent," this requirement must be met as part of each specification contained in this reference standard. 2

The operating limits shown are the most common in the oil industry. The Contractor is responsible for checking and reviewing service fluid conditions for which the Piping Material Specifications are used in the specific project to ensure that they are the appropriate concentration, pressure, temperature, material specification and corrosion tolerance conditions in accordance with the Piping Material Specification gi ven in this annex. 3

The information contained in the column with the heading “Heat Treat” is separate from the manufacturing process required by the piping and its components according to manufacturing processes based on material specifications in ASTM designation or equivalent, such as: normalizing, thermal stabilization, grain size, and equivalent carbon and impact tests, among others. See Paragraph 8.1.1.5 (Heat Treating).



NRF-032-PEMEX-2012

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PAGE 100 OF 104

4

This Piping Material Specification only applies for these services at the express request of PEMEX in the project or by specification of the Technologist or Licensor. 5

To see each of the Piping Material Specifications listed, refer to the Annex attached to this reference standard with links to specifications. When a Piping Material Specification indicates two or more valves of the same type, for example a gate valve with design NRF-211-PEMEX-2008, ISO 10434:2004 or ASME B16.34 or equivalent, the supplier or contractor must ask the user (PEMEX) for the type valve that should be specified on the basic data sheets according to the basic design engineering for the project.

Nrf-032-Pemex-2012 - Piping Systems in Industrial Plants

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