ISO/TC 67 - Materials, equipment and offshore structures for petroleum, petrochemical and natural gas industries

This document provides requirements and guidance on planning, selecting, and implementing methods and strategies for monitoring geohazards that can interact with pipelines. This document specifies requirements and recommendations for users regarding the development and initiation of monitoring processes throughout the pipeline life cycle, including the following stages: a) preliminary engineering and route selection phase; b) detailed design phase; c) construction phase; d) operation and maintenance phase. This document also describes the processes and steps for developing a suitable geohazard monitoring program (GHMP). This document applies to geohazard monitoring of new and existing onshore gathering and transportation pipelines and the right-of-way (RoW). This document does not apply to monitoring geohazards that are temporary, such as the stability of spoil piles, temporary cut slopes to facilitate pipeline construction, stability of excavation or trench wall, and access roads.

Le présent document établit les termes et définitions fondamentaux relatifs à la conception, au choix des matériaux, à la construction, aux essais, à l'exploitation, à la maintenance et à l'abandon des systèmes de transport par conduites dans les industries du pétrole et du gaz. Le présent document s'applique à la conception, à la construction, à l'exploitation et à la maintenance des systèmes de conduites pour le transport de pétrole et de gaz. Le présent document ne s'applique pas aux canalisations de processus dans la zone industrielle des entreprises de raffinage du pétrole et des entreprises chimiques.

This document specifies the criteria and minimum requirements for selecting internal coatings (often referred to as linings) for pressurized service within process vessels. The document provides the following: — key factors influencing coating selection; — generic composition of test liquids which can be used as references when evaluating supporting testing evidence for coatings; — principal test methods to be used as evidence of performance when selecting suitable coatings; — supporting evidence to be used in evaluating coatings that is relevant to the potential end use. This document covers types of coatings that are generally available, with properties that are known and documented. It also covers other materials to be evaluated and qualified for use. This document is applicable to process vessels coated at the new construction phase. It can be applied only where the coating is applied directly to the substrate. This document does not cover requirements related to metallic coatings nor weld overlay materials.

This document specifies requirements for downhole thermoplastics lined tubing (TLT) used in the oil and gas industries, including configuration, materials, manufacturing, inspection and testing, documentation, marking, packaging, transportation, storage and use. This document is applicable to downhole thermoplastics lined tubing (TLT) used in contact with media related to oil and gas exploration and production (which involves multiphase flow, as well as water injection). This document is suitable for thermoplastics including but not limited to polyethylene (PE), polyethylene of raised temperature resistance (PE-RT), ultra-high molecular weight polyethylene (PE-UHMW), crosslinked polyethylene (PE-X), polypropylene (PP), unplasticized polyamide (PA-U), polyketone (PK), polyphenylene sulfide (PPS), polyvinylidene fluoride (PVDF), and polyetheretherketone (PEEK) which meet the requirements of relevant design specifications, standards or regulations.

This document defines the requirements for the design, manufacturing, quality control, assembly, testing, and documentation of ball, check, gate, plug, and axial on–off valves for application in subsea pipeline systems for the petroleum and natural gas industries. This document applies to ASME Class 150, 300, 600, 900, 1500, and 2500 valves intended for use in subsea pipelines. Use of these valves for any other purpose is outside the scope of this document. This document is a supplement to API 6DSS, 3rd edition (2017), with Addendum 1 (2019) and Addendum 2 (2022), including Errata 1-3, the requirements of which are applicable with the additions specified in this document.

This document defines the requirements for the design, manufacturing, materials, welding, quality control, assembly, testing, documentation and process control of axial, ball, check, gate and plug valves for application in the oil and gas industries. This document applies to ASME Class 150, 300, 600, 900, 1 500, and 2 500. This document is a supplement to API 6D, 25th edition (2021), the requirements of which are applicable with the additions specified in this document.

This document provides test procedures for evaluating coated proppants used in hydraulic fracturing operation. This document provides a consistent methodology for tests performed on coated proppants used in hydraulic fracturing operations.

This document presents assessment requirements and associated guidance for extending the service life of a pipeline system, as defined in ISO 13623, beyond its specified design life. It applies to both onshore and offshore rigid metallic pipelines and risers [including steel catenary risers (SCRs)]. This document is not directly applicable to the following: — flexible pipelines; — pipelines constructed from other materials, such as glass reinforced plastics or polymers; — umbilicals (control or chemical conveyance service, or both); — topsides equipment and piping (outside of pipeline system limits defined in accordance with local regulatory requirements); — pipeline protection and support structures and components. However, the assessment process defined herein can be applied in the lifetime extension assessment of the above at the discretion of the user. This document addresses life extension, which is a change to the original design premise. It is also applicable to other changes to the design premise, such as maximum allowable operating pressure (MAOP) re-ratings or a change to the conveyed fluids, at the discretion of the user.

This document provides requirements for the design, manufacturing, and layout of onshore and offshore pig traps allowing entry to a pipeline for the launching and receiving of pigs, inspection tools and other equipment to be run through a pipeline, together with the associated pipework, valves and instrumentation. This document does not apply to installations for automatic launchers or to self-contained pigging valves. This document does not apply to temporary pig traps used only for construction phase.

This document provides a uniform reference for tertiary structure items when a tertiary structure is designed and constructed in offshore oil and gas projects. This document covers topside systems for fixed or floating offshore projects not covered by class requirements. This document can be applicable for hull systems and onshore projects when there is consent from relevant stakeholders. This document does not provide class rules from classification societies. This document provides requirements on dimensions of the items but does not include requirements on clearances with other structures. The following tertiary outfitting designs for equipment items are covered in this document: — handrails; — safety gate; — stairs; — spiral stairs; — vertical ladder; — grating; — access hole (manhole); — connection method.

This document specifies the design requirements for architectural supports, in terms of their shape and dimensions, material, strength, etc. This document covers architectural supports of topside and living-quarter regions for fixed or floating offshore oil and gas platforms including lower carbon energy.

This document contains provisions for geotechnical engineering design that are applicable to a broad range of offshore structures, rather than to a particular structure type. This document outlines methods developed for the design of shallow foundations with an embedded length (L) to diameter (D) ratio L/D L/D ≤ 10 (see Clause 7), and long and flexible pile foundations with L/D > 10 (see Clauses 8 and 9). This document also provides guidance on soil-structure interaction aspects for flowlines, risers and conductors (see Clause 10) and anchors for floating facilities (see Clause 11). This document contains brief guidance on site and soil characterization, and identification of hazards (see Clause 6). This document can be applied for foundation design for offshore structures used in the lower carbon energy industry.

This document provides general requirements and recommendations for the development and operation of subsea production/injection systems, from the concept development phase to decommissioning and abandonment. Flexible pipe standards form part of the API 17-series of documents (see 4.3.3); however, this document (technically equivalent to API RP 17A 6th edition) does not generally cover flowlines/pipelines or production/injection risers (associated with flowlines/pipelines). These components form part of a complete subsea production system (SPS), as shown in Figure 1.

This document specifies requirements and guidance for manufacturers of ammonia-fired boilers regarding functional tests performed at the time of design and on-site acceptance tests, in order to meet the required environmental performance. This document stipulates the test methods, the measurement items, the evaluation methods and the test reports for each test. This document is applicable to: a) land boilers used for power generation with an electrical output of 100 MWe or more; b) equipment that uses NH3 of any mixing ratio as fuel; c) boilers with burners for combustion of fuel. This document does not apply to heat recovery steam generators for gas turbines, fluidized bed boiler, stokers, black liquor recovery boiler and process heat transfer equipment (used in petroleum refining).

This document provides testing procedures for evaluating proppants used in hydraulic fracturing and gravel packing operations. NOTE Proppants mentioned in this document refer to sand, ceramic, resin-coated, gravel packing proppants, and other materials used for hydraulic fracturing and gravel packing operations. This document supplements API Std 19C, 2nd edition (2018), the requirements of which are applicable with the exceptions specified in this document. This document provides consistent methodology for testing performed on hydraulic fracturing and/or gravel packing proppants.

This document specifies requirements for lifting sets for use with containers in offshore service, including technical requirements, marking and statements of conformity for single and multi-leg slings, including chain slings and wire rope slings.

This document specifies requirements for the design, manufacture and marking of offshore containers with a maximum gross mass not exceeding 25 000 kg, intended for repeated use to, from and between offshore installations and ships. This document specifies only transport-related requirements.

This document specifies requirements for the periodic inspection, examination and testing of offshore containers, built in accordance with ISO 10855-1 and with a maximum gross mass not exceeding 25 000 kg, and their associated lifting sets, intended for repeated use to, from and between offshore installations and ships. Inspection requirements following damage and repair of offshore containers are also included.

This document provides guidelines for green manufacturing and lower carbon emission practices of oil and gas-field equipment and materials used in the hydrocarbon industries. The guidelines include the establishment of a green attribute system and implementation of sound practices for green manufacturing and lower carbon emission, such as green design, manufacturing, remanufacturing, evaluation and management. This document is applicable to organizations involved in the design, construction, engineering, commissioning, operations, maintenance, decommissioning and reuse of materials, equipment, installations and process systems applied in the hydrocarbon industries.

This document provides requirements and recommendations for the design, construction and operation of newly installed liquefied natural gas (LNG) railway loading and unloading facilities for use on onshore LNG terminals, LNG satellite plants, handling LNG tank wagons or tank containers engaged in international trade. The designated boundary limits of this document are between the LNG terminal’s inlet/outlet piping headers at the beginning of the rail loading or unloading area and the rail track area used for LNG tank wagons and containers. It is applicable to all rail loading bays, weighbridge(s) and related subsystems.

This document provides the methods for the testing of well cement formulations to determine the dimension changes during the curing process (cement hydration) at atmospheric and elevated pressure and the stress generated by expansion in a confined environment under elevated temperature and pressure.

This document provides general principles, requirements and recommendations for the assessment of stability of fibre-reinforced composite materials for service in equipment used in oil and gas production environments. This document describes the procedures for comparative testing of composite materials consisting of polymers (thermoplastics and thermosets) and re-enforcing materials e.g. glass, carbon, aramid and metals as continuous fibres or woven fabric used in equipment for oil and gas production. Testing and characterization of neat resins and fibre products are beyond the scope of this document. The equipment considered includes, but is not limited to, non-metallic pipelines, piping, liners and downhole tool components. Blistering by rapid gas decompression, coatings and compounded particulate- and short fibre-reinforced composites are excluded from the scope of this document.

This document specifies testing, performance, and marking requirements for casing bow-spring centralizers to be used in oil and natural gas well construction. The procedures give guidance on verification testing for the manufacturer’s design, materials, and process specifications, and periodic testing to confirm the consistency of product performance. This specification is not applicable to other devices, such as rigid centralizers and cement baskets, or bow-spring centralizers used for other purposes (e.g., wireline tools, gravel pack, inner string). This document is a supplement to API Spec 10D 7th edition (2021), the requirements of which are applicable with the exceptions specified in this document.

This document provides a method to calculate the greenhouse gas (GHG) emissions during natural gas production (onshore or offshore), gas processing and gas transport to liquefied natural gas (LNG) liquefaction plant. NOTE It can be applied to other gases as biogas or non-traditional types of natural gas. This document covers all facilities associated with producing natural gas, including: — drilling (exploration, appraisal, and development) and production wells; — gas gathering network and boosting stations (if any); — gas processing facilities (if any), transport gas pipelines with compression stations (if any) up to inlet valve of LNG liquefaction plant. This document covers facilities associated with producing other products (such as, but not limited to, domestic gas, condensate, Liquefied Petroleum Gas (LPG), sulphur, power export) to the extent required to allocate GHG emissions to each product. This document covers the upstream facilities “under operation”, including emissions associated with commissioning, initial start-up and restarts after maintenance or upset. This document does not cover the exploration, construction and decommissioning phases or the losses from vegetation coverage. This document covers all GHG emissions associated with production, process and transport of natural gas to the LNG liquefaction plant. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization, as defined in ISO 6338-1. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy. Gases covered include CO2, CH4, N2O and fluorinated gases. This document does not cover compensation. This document defines preferred units of measurement and necessary conversions. This document also recommends instrumentation and estimations methods to monitor and report GHG emissions. Some emissions are measured; and some are estimated.

This document specifies the technical delivery conditions for bends made by the induction bending process for use in pipeline transportation systems for the petroleum and natural gas industries as defined in ISO 13623. This document is applicable to induction bends made from seamless and welded pipe of unalloyed or low-alloy steels. NOTE These are typically C-Mn steels or low-alloy steels that are appropriate for the corresponding level and grade of line pipe in accordance with ISO 3183. This document specifies the requirements for the manufacture of two product specification levels (PSLs) of induction bends corresponding to product specification levels given for pipe in ISO 3183. This document is not applicable to the selection of the induction bend PSL. This document is not applicable to pipeline bends made by other manufacturing processes.

This document provides requirements for the design, design verification and validation, quality control, functional evaluations and storage of submersible linear motor (SLM) systems. This document is applicable to components of submersible linear motors including stators, movers and motor lead extension cables. This document also specifies design validation performance rating requirements and functional evaluation for SLM. Equipment not covered by this document includes pumps and other fittings, power cables and drive systems.

This document specifies objectives, functional requirements and guidelines for emergency response (ER) measures on installations used for the development of offshore hydrocarbon resources. It is applicable to: — fixed offshore structures; — floating systems for production, storage and off-loading. NOTE For mobile offshore units, the ER plans developed in conformance with the requirements and recommendations of the International Maritime Organization (IMO) are generally adequate for the normal, independent operation of the unit in most locations. The following aspects of ER planning are not generally addressed by IMO and are topics intended for inclusion in the scope of this document where relevant to the specific installation: — area evacuation, e.g. precautionary evacuation in areas of tropical revolving storms; — combined operations (where an integrated command and ER system is relevant); — arctic operations; — uncontrolled flow from a well.

This document specifies the technical delivery conditions for corrosion-resistant alloy seamless products for casing, tubing, coupling stock and accessory material (including coupling stock and accessory material from bar) for two product specification levels: PSL-1, which is the basis of this document; PSL-2, which provides additional requirements for a product that is intended to be both corrosion and cracking resistant for the environments and qualification method specified in Annex G and in the ISO 15156 series or NACE MR0175. This document contains no provisions relating to the connection of individual lengths of pipe. Demonstration of conformance to ISO 15156-3:2020 or NACE MR0175-2021 of material affected by end sizing, connection manufacture or welding operations is outside the scope of this document. This document contains provisions relating to marking of tubing and casing after threading. This document is applicable to the following five groups of products: a) group 1, which is composed of stainless alloys with a martensitic or martensitic/ferritic structure; b) group 2, which is composed of stainless alloys with a ferritic-austenitic structure, such as duplex and super-duplex stainless alloy; c) group 3, which is composed of stainless alloys with an austenitic structure (iron base); d) group 4, which is composed of nickel-based alloys with an austenitic structure (nickel base); e) group 5, which is composed of bar only (Annex F) in age-hardened (AH) nickel-based alloys with austenitic structure.

This document specifies requirements for surface preparation, materials, application, inspection and testing of internal coating lining systems that are intended to be applied on internal surfaces of steel storage tanks of crude oil, hydrocarbons and water for corrosion protection. It covers both new construction and maintenance works of tank internal coating and lining as well as the repair of defective and deteriorated coating/lining. This document also provides requirements for shop performance testing of the coated/lined samples and the criteria for their approval.

This document gives a method for determining the resistance to cracking of steel pipes in sour service. This test method employs a full-scale test specimen consisting of a short length of pipe (a ‘full ring’), sealed at each end to contain the sour test environment within. The test method applies to any pipe; seamless, longitudinally welded (with or without filler), helical welded, and to girth welds between pipes. NOTE 1 The specimen is usually a pipe but can also consist of flange neck or section of a bend, or other tubular component or a combination of the above. NOTE 2 This test method can also be used for corrosion resistant alloys (CRAs). The method utilizes ovalization by mechanical loading to produce a circumferential stress, equal to the target hoop stress, at two diametrically opposite locations on the inside surface of the test specimen. The test specimen is then subjected to single sided exposure to the sour test environment. NOTE 3 The test also allows measurement of hydrogen permeation rates.

This document specifies the objectives and functional requirements for the control and mitigation of fires and explosions on offshore installations used for the development of hydrocarbon resources in oil and gas industries. The object is to achieve: safety of personnel; protection of the environment; protection of assets; minimization of financial and consequential losses of fires and explosions. This document is applicable to the following: fixed offshore structures; floating systems for production, storage, and offloading. Mobile offshore units and subsea installations are excluded, although many of the principles contained in this document can be used as guidance.

This document specifies requirements and gives recommendations for the pre-installation surveys, design, materials, equipment, fabrication, installation, commissioning, operation, inspection and maintenance of cathodic protection (CP) systems for offshore pipelines for the petroleum, petrochemical and natural gas industries as defined in ISO 13623. Flexible pipelines, in-field flowlines, spools and risers are included in this document. Subsea production and injection equipment and structures are not included in this document. This document is applicable to carbon steel, stainless steel and flexible metallic pipelines in offshore service. This document is applicable to retrofits, modifications and repairs made to existing pipeline systems. This document is applicable to all types of seawater and seabed environments encountered in submerged conditions and on risers up to mean water level.

This document: — provides the general part of the method to calculate the greenhouse gas (GHG) emissions throughout the liquefied natural gas (LNG) chain, a means to determine their carbon footprint; — defines preferred units of measurement and necessary conversions; — recommends instrumentation and estimation methods to monitor and report GHG emissions. Some emissions are measured; and some are estimated. This document covers all facilities in the LNG chain. The facilities are considered “under operation”, including emissions associated with initial start-up, maintenance, turnaround and restarts after maintenance or upset. The construction, commissioning, extension and decommissioning phases are excluded from this document but can be assessed separately. This document covers all GHG emissions. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization. Scope 1, 2 and 3 are defined in this document. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy. This document describes the allocation of GHG emissions to LNG and other hydrocarbon products where other products are produced (e.g. LPG, domestic gas, condensates, sulfur). This document does not cover specific requirements on natural gas production and transport to LNG plant, liquefaction, shipping and regasification. This document is applicable to the LNG industry.

This document gives general guidelines for the design, material selection, qualification, certification, and testing details of hose assemblies for Liquefied Natural Gas (LNG) marine transfer applications. The transfer hose assemblies are part of transfer systems (it means that they may be fitted with ERS, QCDC, handling systems, hydraulic and electric components etc.) To avoid unnecessary repetition, cross-references to EN ISO 16904 and EN 1474-3 are made for all compatible items, and for references, definitions and abbreviations. Where additional references, definitions and abbreviations are required specifically for LNG hose assemblies, they are listed in this document.

This document provides requirements, guidance and information for the design and fabrication of topsides structure for offshore structures, including in-service, pre-service and post-service conditions. The actions on topsides structure and the action effects in structural components are derived from this document, where necessary in combination with other International Standards in the ISO 19901 series (e.g. ISO 19901-1 for wind actions - see 7.6.2, ISO 19901-2 for seismic actions - see 7.7) and ISO 19902 for fatigue design (see 6.7). This document is applicable to the following: — topsides of fixed offshore structures; — discrete structural units placed on the hull structures of floating offshore structures and mobile offshore units; — topsides of arctic offshore structures, excluding winterization (see ISO 19906). If any part of the topsides structure forms part of the primary structure of the overall structural system which resists global platform actions, the requirements of this document are supplemented with applicable requirements in ISO 19902, ISO 19903, ISO 19904-1, ISO 19905-1, ISO 19905-3 and ISO 19906. For those parts of floating offshore structures and mobile offshore units that are chosen to be governed by the rules of a recognized classification society, the corresponding class rules supersede the associated requirements of this document. This document also addresses prevention, control and assessment of fire, explosions and other accidental events. The fire and explosion provisions of this document can be applied to those parts of the hulls of floating structures and mobile offshore units that contain hydrocarbon processing, piping or storage. NOTE Requirements for structural integrity management are presented in ISO 19901-9. This document applies to structural components including the following: — primary and secondary structure in decks, module support frames and modules; — flare structures; — crane pedestal and other crane support arrangements; — helicopter landing decks (helidecks); — permanent bridges between separate offshore structures; — masts, towers and booms on offshore structures. This document provides requirements for selecting and using a national building standard with a correspondence factor for determining the resistance of rolled and welded non-circular prismatic components and their connections.

This document specifies requirements and provides recommendation and guidance for the elevated site-specific assessment (SSA-E) of independent leg jack‑up units for use in the petroleum and natural gas industries. It addresses: a) occupied non-evacuated, occupied evacuated and unoccupied jack‑ups; b) the installed (or elevated) phase at a specific site. It also addresses the requirement that the as-installed condition matches the assumptions used in the assessment. This document does not address the site-specific assessment of installation and removal (SSA-I). To ensure acceptable reliability, the provisions of this document form an integrated approach, which is used in its entirety for the site-specific assessment of a jack‑up. When assessing a jack-up operating in regions subject to sea ice and icebergs, it is intended that the assessor supplements the provisions of this document with the relevant provisions relating to ice actions contained in ISO 19906 and procedures for ice management contained in ISO 35104. This document does not address design, transit to and from site, or installation and removal from site. This document is applicable only to independent leg mobile jack-up units that are structurally sound and adequately maintained, which is normally demonstrated through holding a valid recognized classification society, classification certificate. Jack‑ups that do not hold a valid recognized classification society certificate are assessed according to the provisions of ISO 19902, supplemented by methodologies from this document, where applicable. NOTE 1 Well conductors can be a safety-critical element for jack‑up operations. However, the integrity of well conductors is not part of the site-specific assessment process for jack‑ups and is, therefore, not addressed in this document. See A.1 for guidance on this topic. NOTE 2 RCS rules and the IMO MODU code (International Maritime Organisation Mobile Offshore Drilling Unit code) provide guidance for the design of jack-ups.

The purpose of this document is to provide a uniform standard for monorail beams and padeyes when these structures are designed and constructed in offshore projects. This document specifies the design and material requirements for mechanical handling including monorail beams and padeyes during operations of offshore facilities. This document specifies the standard shapes and dimensions of monorail beams and padeyes and provides material requirements for these bulk materials. This document is applicable to the structures of monorail beams and padeyes for topside systems for fixed or floating offshore projects.

This document provides a set of common supplementary requirements for the most frequently used materials in upstream oil and gas piping systems. This document is applicable to offshore and onshore production facilities, processing and gas liquefaction plants. The materials covered in this document are intended to be used in the following piping systems services: — category D, category M, normal and high pressure, according to ASME B31.3; — sour environments as defined in the ISO 15156 series. NOTE For the purposes of this document, ANSI/NACE MR0175 is equivalent to the ISO 15156 series, and ANSI/NACE MR0103 is equivalent to ISO 17945. This document does not provide guidelines for material selection. The selection of suitable materials for a specific service including any necessary additional material requirements remains the responsibility of the end user. This document does not cover requirements related to: — sulfide stress cracking (SSC) in corrosive petroleum refining environments included in ISO 17945; — non-metallic piping systems according to ASME B31.3 or the ISO 14692 series; — marine piping systems, e.g. ballasting piping system, covered by classification rules; — subsea production systems; — downhole equipment; — transportation pipeline systems, including flowlines, designed in accordance with a recognized pipeline design code. Common requirements related to manufacture, inspection and procurement of piping and valve parts are included in Annex A and Annex B, providing material datasheets and element datasheets, respectively. These material and element datasheets can be applied for applications other than piping systems, e.g. pressure vessels and pumps based upon assessment of the end user and conformance with the selected design code for the relevant equipment. This document is not intended to limit the use of alternative materials or grades within a referenced material standard. Where the use of alternative materials/grades are considered appropriate, the end user is responsible for specifying any additional requirements necessary to meet the design code or specification.

This document specifies requirements and provides guidance for the selection, design, specification, operation, and maintenance of flares and related combustion and mechanical components used in pressure-relieving and vapor-depressurizing systems for petroleum, petrochemical, and natural gas industries. While this document is primarily intended for onshore facilities, guidance related to offshore applications is included. Guidance and best practices for the selection, specification, and mechanical details for flares and on the design, operation, and maintenance of flare combustion and related equipment is also provided. This document is a supplement to API 537, 3rd edition (2017) including Addendum 1, the requirements of which are applicable with the exceptions specified in this document.

This document specifies requirements for project specific product and process qualification of field applied wet thermal insulation systems applied at interfaces (e.g. field joints) and pre-fabricated insulation in the petroleum and natural gas industries. This document is applicable to wet thermal insulation systems submerged in seawater. This document is not applicable to: — the project qualification of anticorrosion coatings or the requirements for application thereof; — thermal insulation in the annulus of a steel pipe-in-pipe system.

This document specifies requirements for project specific product and process qualification of wet thermal insulation systems applied to pipelines in a factory setting and subsea equipment in the oil and gas industries. This document is not applicable to: — pre-fabricated insulation; — thermal insulation in the annulus of a steel pipe-in-pipe system; — maintenance works on existing installed wet thermal insulation systems; — project qualification of anticorrosion coatings or the requirements for application thereof.

This document specifies requirements for the validation of wet thermal insulation systems applied to pipelines and subsea equipment in the oil and gas industry. This document is applicable to wet thermal insulation systems submerged in seawater. This document is not applicable to: — maintenance works on existing installed wet thermal insulation systems; — qualification for anti-corrosion coating; — thermal insulation in the annulus of a steel pipe-in-pipe system.

This document specifies requirements for the fabrication, installation, welding, inspection, examination and testing of new, metallic piping systems , within temperature range limits for the materials meeting the requirements of ASME B31.3, on fixed and floating offshore production facilities and onshore production, processing and gas liquefaction plants. For piping systems above pressure class 2500, the requirements of chapter IX of ASME B31.3 shall be complied with, in addition to the requirements stated in this standard. This document is applicable to all pressure retaining components and any non-pressure retaining component, such as a member of a pipe support, welded directly to a pressure retaining component. This document is not applicable to the following: — marine-related piping systems, e.g. ballasting piping systems, systems covered by classification societies; — metallic tubing used for subsea umbilical systems; NOTE 1 Reference can be made to ISO 13628-5 or API Spec 17E for welding and examination of these components. — piping systems with corrosion resistant cladding (either integrally clad or mechanically lined) or weld overlay, including buttering and associated dissimilar welds; NOTE 2 Reference can be made to DNV-RP-B204 for welding and examination of these systems. — refractory alloys [with exception of CP titanium Grade 1 (UNS R50250) or Grade 2 (UNS R50400)]; — non-metallic piping assemblies; — transportation pipeline systems, including flow-lines, designed in accordance with a recognized pipeline design code.

This document specifies requirements for the design, design verification and validation, manufacturing and data control, performance ratings, functional evaluations, handling and storage of tubing-deployed electrical submersible pump (ESP) systems. Additionally, this document provides requirements for assembled ESP system. This document is applicable to those ESP related components meeting the definition of centrifugal pumps, including gas handling devices, discharge heads, seal chamber sections, intake systems, mechanical gas separators, asynchronous 3 phase - 2 pole induction motors (herein motor), shaft couplings, downhole power cables (herein power cables), motor lead extension, and pothead. Components supplied under the requirements of this document exclude previously used subcomponents, except where the use of such subcomponents is as defined in this document (Clause 9). This document addresses design validation performance rating requirements by component (see Annex A), requirements for determining ratings as an assembled system (see Annex B), functional evaluation: single component (see Annex C) and cable reference information (see Annex D). This document addresses functional evaluation guidelines for assembled ESP systems, establishing recommended operating range (ROR) of the ESP system (see Annex F), example user/purchaser ESP functional specification form (see Annex G), considerations for the use of 3-phase low and medium voltage adjustable speed drives for ESP applications (see Annex H), analysis after ESP use (see Annex I), downhole monitoring of ESP assembly operation (see Annex J), information on permanent magnet motors for ESP applications (see Annex K) and users guide (see Annex L). This document also includes a user guide that offers a high-level process workflow when applying this document. This document does not apply to: wireline and coiled tubing-deployed ESP systems, motor shrouds and pump shrouds, electric penetrators and feed-through systems, cable clamps and banding, centralizers, intake screens, passive gas separators, by-pass tools, check and bleeder valves, component adaptors, capillary lines, electric surface control equipment, downhole permanent magnet motors and non-conventionally configured ESP systems such as inverted systems. This document does not apply to Repair and redress equipment requirements.

This document specifies requirements and provides recommendations and guidelines for marine soil investigations regarding: a) objectives, planning and execution of marine soil investigations; b) deployment of investigation equipment; c) drilling and logging; d) in situ testing; e) sampling; f) laboratory testing; g) reporting. Although this document focuses on investigations of soil, it also provides guidance, with less detail, for investigations of chalk, calcareous soils, cemented soils and weak rock. Foundation design is not covered by this document. NOTE 1 ISO 19901‑4 and the respective design standards covering foundation design for the specific types of offshore structures to meet the requirements of application specific standards are given on the ISO website. The results from marine geophysical investigations are, when available and where appropriate, used for planning, optimization and interpretation of marine soil investigations. This document neither covers the planning, execution and interpretation of marine geophysical investigations nor the planning and scope of geohazard assessment studies, only the corresponding marine soil investigations aspects thereof. NOTE 2 ISO 19901-10 covers the planning, execution and interpretation of marine geophysical investigations. This document specifies requirements and provides guidance for obtaining measured values and derived values. This document excludes requirements for determination of design values and representative values. Limited guidance is provided in 11.3 related to data interpretation. This document is intended for clients, soil investigation contractors, designers, installation contractors, geotechnical laboratories and public and regulatory authorities concerned with marine soil investigations for any type of offshore structures, or geohazard assessment studies.

This document specifies requirements and gives recommendations on the integrity assessment of pipelines of various applications as part of pipeline systems. This document is mainly applicable to onshore pipeline systems, connecting wells, production plants, process plants, refineries and storage facilities, including any section of a pipeline constructed within the boundaries of such facilities for connection purpose, according to ISO 19345-1. The principles can also be used for offshore pipelines where applicable and practical. This document applies to rigid, steel pipelines. It is not applicable for flexible pipelines or those constructed from other materials, such as glass-reinforced plastics. This document does not cover all conditions which might be related to pipeline integrity. A competent pipeline integrity engineer can evaluate whether additional requirements are necessary. This document does not cover the assessment of pipeline defect(s) found during fabrication/construction or installation, which would need to be done in accordance with the applicable standards of design, construction, material procurement and welding process applicable at that time. However, this document can be applied to the ongoing monitoring and assessment of known flaws from the time of construction.

This document provides a method to calculate the GHG emissions from an LNG liquefaction plant, onshore or offshore. The frame of this document ranges from the inlet flange of the LNG plant’s inlet facilities up to and including the offloading arms to truck, ship or railcar loading. The upstream supply of gas up to the inlet flange of the inlet facilities and the distribution of LNG downstream of the loading arms are only covered in general terms. This document covers: — all facilities associated with producing LNG, including reception facilities, condensate unit (where applicable), pre-treatment units (including but not limited to acid gas removal, dehydration, mercury removal, heavies removal), LPG extraction and fractionation (where applicable), liquefaction, LNG storage and loading, Boil-Off-Gas handling, flare and disposal systems, imported electricity or on-site power generation and other plant utilities and infrastructure (e.g. marine and transportation facilities). — natural gas liquefaction facilities associated with producing other products (e.g. domestic gas, condensate, LPG, sulphur, power export) to the extent required to allocate GHG emissions to the different products. — all GHG emissions associated with producing LNG. These emissions spread across scope 1, scope 2 and scope 3 of the responsible organization. Scope 1, 2 and 3 are defined in this document. All emissions sources are covered including flaring, combustion, cold vents, process vents, fugitive leaks and emissions associated with imported energy. The LNG plant is considered “under operation”, including emissions associated with initial start-up, maintenance, turnaround and restarts after maintenance or upset. The construction, commissioning, extension and decommissioning phases are excluded from this document but can be assessed separately. The emissions resulting from boil-off gas management during loading of the ship or any export vehicle are covered by this document. The emissions from a ship at berth, e.g. mast venting are not covered by this document. This document describes the allocation of GHG emissions to LNG and other hydrocarbon products where other products are produced (e.g. LPG, domestic gas, condensates, sulphur, etc.). This document defines preferred units of measurement and necessary conversions. This document also recommends instrumentation and estimations methods to monitor and report GHG emissions. Some emissions are measured and some are estimated. This document is applicable to the LNG industry. Applications include the provision of method to calculate GHG emissions through a standardized and auditable method, a means to determine their carbon footprint.