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

This document specifies requirements and gives recommendations for the qualification and design, installation, testing and integrity management for the external application of composite repair systems to corroded or damaged piping and pipelines, tanks and vessels.

This document gives requirements for the design, fabrication, installation, commissioning and integrity management of workover rigs on offshore fixed platforms. This document is not applicable to workover equipment: installed on mobile or floating offshore units; intended for onshore use; coiled tubing unit or snubbing unit.

This document defines fundamental definitions for enhanced oil recovery (EOR) concepts and core methodologies, specifically addressing thermal recovery, gas flooding, chemical flooding, and microbial enhanced oil recovery technologies.

This document specifies requirements and guidance for the installation on and removal from site of independent leg jack‑ups for use in the oil and gas industries including lower carbon energy. It addresses the assessment of: the installation operation from when the jack-up enters the defined safety zone of the host platform or the intended site to when it is elevated to the operating hull elevation above LAT and is ready for operations; the removal operation from when the jack-up is ready to jack-down to when it departs the defined safety zone. NOTE 1 Whilst this document is for independent leg jack-ups, many of the provisions can be applied to mat-supported jack-ups. When the jack-up has propulsion assist or is self-propelled, the provisions of this document related to positioning can be replaced or supplemented as appropriate. This document excludes the move of the jack-up between sites and elevated operations, which are covered respectively by IMO/Class and ISO 19905-1. NOTE 2 Whilst this document addresses the installation and removal of a jack-up at a site, RMPs normally include the move of the jack-up between sites (see example RMP in Annex E).

This document provides requirements for subsurface flow-control devices used in side-pocket mandrels intended for use in the worldwide petroleum and natural gas industry. This document addresses injection-pressure-operated (IPO), production-pressure-operated (PPO), pilot, orifice, tubing-retrievable, and dummy flow-control devices. It includes requirements for selecting, designing, manufacturing, quality control, testing, and preparation for the shipping of flow-control devices. Additionally, it includes information regarding performance testing and calibration requirements. The installation and retrieval of flow-control devices is outside the scope of this document. Additionally, this document is not applicable to flow-control devices with concentric axes. This document does not include requirements for side-pocket mandrels, running, pulling, kick-over tools, or latches. Reconditioning of used flow-control devices is outside the scope of this document. This document supplements API Spec 19G2, 2nd edition (2020), the requirements of which are applicable with the exceptions specified in this document.

This document provides two broad types of requirements for the determination and use of meteorological and oceanographic (metocean) conditions for the design, construction and operation of offshore structures: those related to the determination of environmental conditions in general, together with the metocean parameters that are required to adequately describe them; those related to the characterization and use of metocean parameters for the design, the construction activities or the operation of offshore structures. This document covers the following environmental conditions and metocean parameters: extreme and abnormal values of metocean parameters that recur with given return periods that are considerably longer than the design service life of the structure; long-term distributions of metocean parameters in the form of cumulative, conditional, marginal or joint statistics of metocean parameters; normal environmental conditions that are expected to occur frequently during the design service life of the structure. Metocean parameters specified in this document are applicable to: the determination of actions for the design of new structures; the determination of actions for the assessment of existing structures; the site-specific assessment of mobile offshore units; the determination of limiting environmental conditions, weather windows, actions and action effects for pre-service and post-service situations (i.e. fabrication, transportation and installation or decommissioning and removal of a structure); the operation of the platform, where appropriate. It is beyond the scope of this document to provide detailed instructions that can be followed to produce reliable estimates of extreme or abnormal conditions in all areas and in all cases.

This document specifies methodologies for: the design, analysis and evaluation of stationkeeping systems for floating offshore structures; the assessment of stationkeeping systems for site-specific applications of mobile offshore units and construction units. Originally developed for floating structures used in the oil and gas industry, this document is now also used in the renewable energy sector. The extent of application of this document to floating structures used in other industries is at the discretion of the relevant standard entity and its users. For example, IEC 61400-3-2 for floating wind applies this document to determine stationkeeping system responses while incorporating its own load conditions, safety factors, and environmental return periods. This document is applicable to the following types of stationkeeping systems, which are either covered directly in this document or through reference to other guidelines: spread mooring systems; single point mooring systems; dynamic positioning systems; thruster-assisted mooring systems. This document is not applicable to: stationkeeping systems which do not have redundancy against failure of any single component, e.g., single anchor leg moorings (SALMs); stationkeeping systems which use any means other than mooring lines or thrusters such as tower soft yoke systems, or tension leg platforms (TLPs) that use tendons. The requirements for this document address spread mooring systems and single point mooring systems with mooring lines composed of steel chain, steel wire or synthetic fibre rope. This document is applicable to all aspects of the life cycle of mooring systems. It includes requirements relating to the selection of mooring components, mooring system configuration and performance, components design, installation, post-installation survey, and as-installed assessments as needed for mooring integrity management. For mooring systems deployed in ice-prone environments, additional requirements in ISO 19906 apply.

This document contains requirements for seismic design and assessment of offshore structures. This document includes recommendations for the effects of seismic events on floating structures. This document addresses specifically the design and assessment of offshore structures subjected to earthquake-induced ground motions. It also covers briefly other geologically induced hazards such as liquefaction, slope instability, fault surface displacement, tsunamis, mud volcanoes and shock waves. This document provides requirements for site-specific probabilistic seismic hazard analysis for offshore structures in high seismic areas and for offshore structures with high consequence levels.

This document specifies requirements and gives recommendations for the pre-installation surveys, design, materials, equipment, installation, commissioning, operation, inspection, and maintenance of cathodic protection systems for the external surface of on-land pipelines. This document is applicable to on-land pipelines and piping systems used in other industries and transporting other media such as industrial gases, waters, or slurries. Throughout this document, on-land pipelines mean: pipelines that are buried; landfalls of offshore pipeline sections protected by onshore based cathodic protection installations; immersed sections of on-land pipelines such as river or lake crossings. This document is applicable to pipelines of carbon steel, stainless steel, cast iron, galvanized steel, and copper. This document does not apply to pipelines made of reinforced concrete (see ISO 12696).

This document provides general principles, requirements and recommendations for the assessment of the stability of thermoset materials that include short fibre filled or particle filled resins and exclude continuous fibre reinforced composites for service in equipment used in oil and gas exploration and production environments. These procedures can be adapted for application within low-carbon energy environments. This document also provides guidance for quality assurance. This document addresses the resistance of thermosets to the deterioration in properties that can be caused by physical or chemical interaction with produced and injected oil and gas-field media, and with chemical treatment. Interaction with sunlight and ionizing radiation are excluded from the scope of this document. This document is not necessarily applicable to equipment used in refining or downstream processes and equipment. The equipment considered includes, but is not limited to, non-metallic pipelines, piping, liners, seals, gaskets and washers. Applications for short-term exposure include pump-down plugs, bridge plug components, line wiper plugs, balls, setting tools and fracking tools. Applications for long-term exposure include bearings and washers. This document excludes tubular products, tanks and similar items produced from continuous fibre reinforced materials. Blistering by rapid gas decompression is not included in the scope of this document. This document applies to the assessment of the stability of thermoset materials in simulated hydrocarbon production conditions to aid the selection of materials for equipment designed and constructed using conventional design criteria. Designs utilizing other criteria are excluded from the scope of this document.

This document specifies requirements and guidance for production assurance and reliability management as applicable to the assets and operations associated with exploration drilling, exploitation, processing and transport of petroleum, petrochemical and natural gas resources. It covers the assets and associated activities for upstream, midstream, downstream and petrochemical business categories. It focuses on the production assurance of oil and gas with respect to production and associated activities and covers the analysis of reliability and maintenance of the equipment. This includes a variety of associated systems and equipment in the oil and gas value chain. Production assurance addresses not only hydrocarbon production, but also associated activities such as drilling, pipeline installation and subsea intervention. The document also supports production assurance and reliability management for lower carbon energy assets and associated operations, e.g. carbon capture and storage (CCS), hydrogen, ammonia, and wind energy. It describes the processes, activities, requirements and guidelines for systematic management, effective planning, execution and use of production assurance and reliability technology. This document defines 12 processes, of which seven are denoted as core production assurance processes and addressed in this document. The remaining five processes are denoted as interacting processes and while they are outside the scope of this document, information is provided as to how they relate to production assurance and reliability management. The relationship of the core production assurance processes with these interacting processes, however, is within the scope of this document as the flow of information to and from these latter processes is required to ensure that production assurance requirements are fulfilled. The document specifies how to establish and execute a production assurance programme (PAP) and a reliability management programme (RMP). This document lists processes and activities that can be initiated to add value for the stakeholder (e.g. operator), where the selected process can depend on their business strategy and application area. This document is intended for the following users and associated activities by their personnel: Operators: Production assurance and reliability management activities. Related activities include project management and control, technology development, technology qualification, concept and system design, risk management (including HSE), integrity management, and maintenance management. Contractors: Activities by the main contractor for engineering, procurement, construction, drilling, installation, operation, maintenance services, etc. Vendors: Activities by manufacturer or supplier related to equipment design and quality management, technology development and qualification. Authorities: Activities by regulatory bodies to ensure HSE, resource utilization and economic efficiency in operations. Consultants: Consultancy services aimed at supporting production assurance and reliability management. Universities: Activities associated with educating industry professionals, as well as conducting fundamental or applied research projects, when related to production assurance, reliability management, and technology development. This includes improvement of the methods and frameworks described herein. Research institutions: Research activities related to production assurance, reliability management, and technology development. This includes equipment qualification testing and advanced engineering assessments using the methods and frameworks described herein.

This document specifies the standard cost coding system (SCCS) that classifies costs, work hours and quantities for the assets and operations associated with the oil and gas industries including lower carbon energy activities. This document covers all life cycle phases of the assets and operations. The SCCS is applicable to: cost estimation; benchmarking; cost monitoring and reporting; collection of quantities, work hours and cost data; exchange of cost data among organizations; implementation in cost systems. This document also provides a basis for the establishment of: cost classification relevant to cost accounting rules, specific contractual agreements, local requirements for cost reporting to national bodies, government rules and tax regulations, authorization for expenditure, billing purposes, etc.; unique project breakdown structures (e.g. work breakdown structures, contract breakdown structures and organizational breakdown structures) or asset breakdown structures (e.g. tag or system codes and area or module breakdown structures). This document is intended for the following users: operators or owners; contractors; vendors, manufacturers or suppliers; authorities or regulatory bodies; benchmarking companies; consultants.

This document specifies the performance test procedures for acidizing fluids used as completion fluids and materials in oil and gas well operations. NOTE The acidizing fluids mentioned in this document refer to hydrochloric acid, mud acid, polymer-based acid acidizing fluids, emulsified acid acidizing fluids, etc., used in acidizing operations of oil and gas wells, including fundamental acid solution and acidizing fluid system with additives, such as corrosion inhibitor and ferric ion (Fe3+) stabling agent.

This document specifies the requirements for qualification, application, inspection, testing handling and storage of materials for plant application of single-layer fusion-bonded epoxy (FBE) coatings applied externally for the corrosion protection of bare steel pipe for use in pipeline transportation systems for oil and gas industries as defined in ISO 13623. NOTE Pipes coated in accordance with this document are considered suitable for additional protection by means of cathodic protection.

This document specifies the requirements for qualification, application, inspection, testing, handling and storage of materials for plant application of two-layer polyethylene coatings (2-layer PE) applied externally for the corrosion protection of bare steel pipe for use in pipeline transportation systems for oil and gas industries as defined in ISO 13623. NOTE Pipes coated in accordance with this document are considered suitable for additional protection by means of cathodic protection.

This document establishes the form of door schedules for offshore projects and provides definitions of listed items for architecture door schedules. It covers architectural doors applied to topsides and living quarters for fixed or floating offshore oil and gas projects.

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, 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 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 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.