This document specifies the technical delivery conditions for steel pipes (casing, tubing and pup joints),
coupling stock, coupling material and accessory material.
By agreement between the purchaser and manufacturer, this document can also be applied to other
plain-end pipe sizes and wall thicknesses.
This document is applicable to the following connections:
— short round thread casing (SC);
— long round thread casing (LC);
— buttress thread casing (BC);
— non-upset tubing (NU);
— external upset tubing (EU);
— integral-joint tubing (IJ).
NOTE 1 For further information, see API Spec 5B.
For such connections, this document specifies the technical delivery conditions for couplings and
thread protection.
NOTE 2 Supplementary requirements that can optionally be agreed for enhanced leak resistance connections
(LC) are given in A.9 SR22.
This document can also be applied to tubulars with connections not covered by ISO or API standards.
This document is applicable to products including the following grades of pipe: H40, J55, K55, N80, L80,
C90, R95, T95, P110, C110 and Q125.
This document is not applicable to threading requirements.
NOTE 3 Dimensional requirements on threads and thread gauges, stipulations on gauging practice, gauge
specifications, as well as, instruments and methods for inspection of threads are given in API Spec 5B.

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This document provides requirements and guidelines for marine geophysical investigations. It is applicable to operators/end users, contractors and public and regulatory authorities concerned with marine site investigations for offshore structures for petroleum and natural gas industries. This document provides requirements, specifications, and guidance for: a) objectives, planning, and quality management; b) positioning; c) seafloor mapping, including instrumentation and acquisition parameters, acquisition methods, and deliverables; d) sub-seafloor mapping, including seismic instrumentation and acquisition parameters, and non-seismic-reflection methods; e) reporting; f) data integration, interpretation, and investigation of geohazards. This document is applicable to investigation of the seafloor and the sub-seafloor, from shallow coastal waters to water depths of 3 000 m and more. It provides guidance for the integration of the results from marine soil investigations and marine geophysical investigations with other relevant datasets. NOTE 1 The depth of interest for sub-seafloor mapping depends on the objectives of the investigation. For offshore construction, the depths of investigation are typically in the range 1 m below seafloor to 200 m below seafloor. Some methods for sub-seafloor mapping can also achieve much greater investigation depths, for example for assessing geohazards for hydrocarbon well drilling. There is a fundamental difference between seafloor mapping and sub-seafloor mapping: seafloor signal resolution can be specified, while sub-seafloor signal resolution and penetration cannot. This document therefore contains requirements for the use of certain techniques for certain types of seafloor mapping and sub-seafloor mapping (similarly, requirements are given for certain aspects of data processing). If other techniques can be shown to obtain the same information, with the same or better resolution and accuracy, then those techniques may be used. Mapping of pre-drilling well-site geohazards beneath the seafloor is part of the scope of this document. NOTE 2 This implies depths of investigation that are typically 200 m below the first pressure-containment casing string or 1 000 m below the seafloor, whichever is greatest. Mapping of pre-drilling well-site geohazards is therefore the deepest type of investigation covered by this document. In this document, positioning information relates only to the positioning of survey platforms, sources and receivers. The processes used to determine positions of seafloor and sub-seafloor data points are not covered in this document. Guidance only is given in this document for the use of marine shear waves (A.8.3.3), marine surface waves (A.8.3.4), electrical resistivity imaging (A.8.3.5) and electromagnetic imaging (A.8.3.6).

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This document specifies requirements and recommendations for the site-specific assessment of mobile floating units for use in the petroleum and natural gas industries. It addresses the installed phase, at a specific site, of manned non-evacuated, manned evacuated and unmanned mobile floating units. This document addresses mobile floating units that are monohull (e.g. ship-shaped vessels or barges); column-stabilized, commonly referred to as semi-submersibles; or other hull forms (e.g. cylindrical/conical shaped). It is not applicable to tension leg platforms. Stationkeeping can be provided by a mooring system, a thruster assisted mooring system, or dynamic positioning. The function of the unit can be broad, including drilling, floatel, tender assist, etc. In situations where hydrocarbons are being produced, there can be additional requirements. This document does not address all site considerations, and certain specific locations can require additional assessment. This document is applicable only to mobile floating units that are structurally sound and adequately maintained, which is normally demonstrated through holding a valid RCS classification certificate. This document does not address design, transportation to and from site, or installation and removal from site. This document sets out the requirements for site-specific assessments, but generally relies on other documents to supply the details of how the assessments are to be undertaken. In general: — ISO 19901‑7 is referenced for the assessment of the stationkeeping system; — ISO 19904‑1 is referenced to determine the effects of the metocean actions on the unit; — ISO 19906 is referenced for arctic and cold regions; — the hull structure and air gap are assessed by use of a comparison between the site-specific metocean conditions and its design conditions, as set out in the RCS approved operations manual; — ISO 13624‑1 and ISO/TR 13624‑2[1] are referenced for the assessment of the marine drilling riser of mobile floating drilling units. Equivalent alternative methodologies can be used; — IMCA M 220 is referenced for developing an activity specific operating guidelines. Agreed alternative methodologies can be used. NOTE RCS rules and the IMO MODU code[13] provide guidance for design and general operation of mobile floating units.

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This document specifies requirements and provides recommendations applicable to the following types
of fixed steel offshore structures for the petroleum and natural gas industries:
— caissons, free-standing and braced;
— jackets;
— monotowers;
— towers.
In addition, it is applicable to compliant bottom founded structures, steel gravity structures, jack-ups,
other bottom founded structures and other structures related to offshore structures (such as underwater
oil storage tanks, bridges and connecting structures).
This document contains requirements for planning and engineering of the design, fabrication,
transportation and installation of new structures as well as, if relevant, their future removal.
NOTE 1 Specific requirements for the design of fixed steel offshore structures in arctic environments are presented
in ISO 19906.
NOTE 2 Requirements for topsides structures are presented in ISO 19901-3; for marine operations in,
ISO 19901-6; for structural integrity management, in ISO 19901-9 and for the site-specific assessment of jack-ups,
in ISO 19905-1.

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This document gives requirements and recommendations for the selection and qualification of carbon
and low-alloy steels for service in equipment used in oil and natural gas production and natural gas
treatment plants in H2S-containing environments, whose failure can pose a risk to the health and safety
of the public and personnel or to the environment. It can be applied to help to avoid costly corrosion
damage to the equipment itself. It supplements, but does not replace, the materials requirements of the
appropriate design codes, standards or regulations.
This document addresses the resistance of these steels to damage that can be caused by sulfide stress
cracking (SSC) and the related phenomena of stress-oriented hydrogen-induced cracking (SOHIC) and
soft-zone cracking (SZC).
This document also addresses the resistance of these steels to hydrogen-induced cracking (HIC) and its
possible development into stepwise cracking (SWC).
This document is concerned only with cracking. Loss of material by general (mass loss) or localized
corrosion is not addressed.
Table 1 provides a non-exhaustive list of equipment to which this document is applicable, including
exclusions.
This document applies to the qualification and selection of materials for equipment designed and
constructed using load controlled design methods. For design utilizing strain-based design methods,
see ISO 15156-1:2020, Clause 5.
Annex A lists SSC-resistant carbon and low alloy steels, and A.2.4 includes requirements for the use of
cast irons.
This document is not necessarily suitable for application to equipment used in refining or downstream
processes and equipment.

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This document describes general principles and gives requirements and recommendations for the
selection and qualification of metallic materials for service in equipment used in oil and gas production
and in natural-gas sweetening plants in H2S-containing environments, where the failure of such
equipment can pose a risk to the health and safety of the public and personnel or to the environment.
It can be applied to help to avoid costly corrosion damage to the equipment itself. It supplements, but
does not replace, the materials requirements given in the appropriate design codes, standards, or
regulations.
This document addresses all mechanisms of cracking that can be caused by H2S, including sulfide stress
cracking, stress corrosion cracking, hydrogen-induced cracking and stepwise cracking, stress-oriented
hydrogen-induced cracking, soft zone cracking, and galvanically induced hydrogen stress cracking.
Table 1 provides a non-exhaustive list of equipment to which this document is applicable, including
exclusions.
This document applies to the qualification and selection of materials for equipment designed and
constructed using load controlled design methods. For design utilizing strain-based design methods,
see Clause 5.
This document is not necessarily applicable to equipment used in refining or downstream processes
and equipment.

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This document gives requirements and recommendations for the selection and qualification of CRAs
(corrosion-resistant alloys) and other alloys for service in equipment used in oil and natural gas
production and natural gas treatment plants in H2S-containing environments whose failure can pose
a risk to the health and safety of the public and personnel or to the environment. It can be applied to
help avoid costly corrosion damage to the equipment itself. It supplements, but does not replace, the
materials requirements of the appropriate design codes, standards, or regulations.
This document addresses the resistance of these materials to damage that can be caused by sulfide
stress cracking (SSC), stress corrosion cracking (SCC), and galvanically induced hydrogen stress
cracking (GHSC).
This document is concerned only with cracking. Loss of material by general (mass loss) or localized
corrosion is not addressed.
Table 1 provides a non-exhaustive list of equipment to which this document is applicable, including
exclusions.
This document applies to the qualification and selection of materials for equipment designed and
constructed using load controlled design methods. For design utilizing strain-based design methods,
see ISO 15156-1:2020, Clause 5.
This document is not necessarily suitable for application to equipment used in refining or downstream
processes and equipment.

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This document specifies requirements and provides recommendations applicable to the following types of fixed steel offshore structures for the petroleum and natural gas industries: ? caissons, free-standing and braced; ? jackets; ? monotowers; ? towers. In addition, it is applicable to compliant bottom founded structures, steel gravity structures, jack-ups, other bottom founded structures and other structures related to offshore structures (such as underwater oil storage tanks, bridges and connecting structures). This document contains requirements for planning and engineering of the design, fabrication, transportation and installation of new structures as well as, if relevant, their future removal. NOTE 1 Specific requirements for the design of fixed steel offshore structures in arctic environments are presented in ISO 19906. NOTE 2 Requirements for topsides structures are presented in ISO 19901-3; for marine operations in, ISO 19901‑6; for structural integrity management, in ISO 19901-9 and for the site-specific assessment of jack-ups, in ISO 19905‑1.

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This European Standard specifies general safety requirements for the design, testing and production of manually operated elevators. The requirements are applicable for on- and off-shore applications of such elevators in the petroleum and petrochemical industries, and are in accordance with EU legislation.
This European Standard does not cover any other type of elevator. It is not applicable to the following types of products:
-   lifting nubbins;
-   lifting plugs;
-   lifting subs;
-   internal gripping devices;
-   equipment for lifting tubular from and onto a vessel.
This list is not exclusive.

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This document specifies the technical delivery conditions for corrosion-resistant alloy seamless
tubular 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.
At the option of the manufacturer, PSL-2 products can be provided in lieu of PSL-1.
NOTE 1 The corrosion-resistant alloys included in this document are special alloys in accordance with
ISO 4948-1 and ISO 4948-2.
NOTE 2 For the purpose of this document, NACE MR0175 is equivalent to the ISO 15156 series.
NOTE 3 Accessory products can be manufactured from coupling stock and tubular material, or from solid bar
stock or from bored and heat heat-treated bar stock as covered in Annex F.
This document contains no provisions relating to the connection of individual lengths of pipe.
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.
NOTE 4 Not all PSL-1 categories and grades can be made cracking resistant in accordance with the
ISO 15156 series and are, therefore, not included in PSL-2.

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This document specifies the technical delivery conditions for corrosion-resistant alloy seamless tubular 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. At the option of the manufacturer, PSL-2 products can be provided in lieu of PSL-1. NOTE 1 The corrosion-resistant alloys included in this document are special alloys in accordance with ISO 4948-1 and ISO 4948-2. NOTE 2 For the purpose of this document, NACE MR0175 is equivalent to the ISO 15156 series. NOTE 3 Accessory products can be manufactured from coupling stock and tubular material, or from solid bar stock or from bored and heat heat-treated bar stock as covered in Annex F. This document contains no provisions relating to the connection of individual lengths of pipe. 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. NOTE 4 Not all PSL-1 categories and grades can be made cracking resistant in accordance with the ISO 15156 series and are, therefore, not included in PSL-2.

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This document specifies general safety requirements for the design, testing and production of powered elevators. The requirements are applicable for on- and off-shore applications of such elevators in the petroleum, petrochemical and natural gas industries.
This document does not cover any other type of elevator. It is not applicable to the following types of products: lifting nubbins, lifting plugs, lifting subs, internal gripping devices, equipment for lifting tubular from and onto a vessel. This list is not exclusive.

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This document specifies the technical delivery conditions for steel pipes (casing, tubing and pup joints), coupling stock, coupling material and accessory material. By agreement between the purchaser and manufacturer, this document can also be applied to other plain-end pipe sizes and wall thicknesses. This document is applicable to the following connections: — short round thread casing (SC); — long round thread casing (LC); — buttress thread casing (BC); — non-upset tubing (NU); — external upset tubing (EU); — integral-joint tubing (IJ). NOTE 1 For further information, see API Spec 5B. For such connections, this document specifies the technical delivery conditions for couplings and thread protection. NOTE 2 Supplementary requirements that can optionally be agreed for enhanced leak resistance connections (LC) are given in A.9 SR22. This document can also be applied to tubulars with connections not covered by ISO or API standards. This document is applicable to products including the following grades of pipe: H40, J55, K55, N80, L80, C90, R95, T95, P110, C110 and Q125. This document is not applicable to threading requirements. NOTE 3 Dimensional requirements on threads and thread gauges, stipulations on gauging practice, gauge specifications, as well as, instruments and methods for inspection of threads are given in API Spec 5B.

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This document specifies general safety requirements for the design, testing and production of powered elevators. The requirements are applicable for onshore and offshore applications of such elevators in the petroleum and petrochemical industries.
This document does not cover any other type of elevator. It is not applicable to the following types of products:
— remote control devices;
— lifting nubbins;
— lifting plugs;
— lifting subs;
— internal gripping devices;
— equipment for lifting tubular from and onto a vessel;
— elevator links or bails.
This list is not exhaustive.
This document is not applicable to powered elevators manufactured before the date of this publication.
NOTE Annex A provides the relation between the clauses of the European Directive on machinery (Directive 2006/42/EC) and this document, for potential significant hazards and the safety requirements dealing with them for powered elevators.

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This document specifies general safety requirements for the design, testing and production of powered elevators. The requirements are applicable for onshore and offshore applications of such elevators in the petroleum and petrochemical industries. This document does not cover any other type of elevator. It is not applicable to the following types of products: — remote control devices; — lifting nubbins; — lifting plugs; — lifting subs; — internal gripping devices; — equipment for lifting tubular from and onto a vessel; — elevator links or bails. This list is not exhaustive. This document is not applicable to powered elevators manufactured before the date of this publication. NOTE Annex A provides the relation between the clauses of the European Directive on machinery (Directive 2006/42/EC) and this document, for potential significant hazards and the safety requirements dealing with them for powered elevators.

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ISO 19905-3 specifies requirements and gives guidance for the site-specific assessment of mobile floating units for use in the petroleum and natural gas industries. It addresses the installed phase, at a specific site, of manned non-evacuated, manned evacuated and unmanned mobile floating units.
ISO 19905-3 addresses mobile floating units that are monohull (e.g. ship-shaped vessels or barges); column-stabilized, commonly referred to as semi-submersibles; or other hull forms (e.g. cylindrical/conical shaped). It is not applicable to tension leg platforms. Stationkeeping can be provided by a mooring system, a thruster assisted mooring system, or dynamic positioning. The function of the unit can be broad, including drilling, floatel, tender assist, etc. In situations where hydrocarbons are being produced, there can be additional requirements.
The requirements of ISO 19905-3 apply to the hull and stationkeeping system for all types of mobile units. The activity specific operating guideline document requirements can be modified to be appropriate to the situation being assessed.
ISO 19905-3 does not address all site considerations, and certain specific locations can require additional assessment.
ISO 19905-3 is applicable only to mobile floating units that are structurally sound and adequately maintained, which is normally demonstrated through holding a valid RCS classification certificate.
ISO 19905-3 does not address design, transportation to and from site, or installation and removal from site.
ISO 19905-3 sets out the requirements for site-specific assessments, but generally relies on other documents to supply the details of how the assessments are to be undertaken. In general:
- ISO 19901‑7 is referenced for the assessment of the stationkeeping system;
- ISO 19904‑1 is referenced to determine the metocean actions on the unit;
- ISO 19906 is referenced for arctic and cold regions;
- the hull structure and airgap are assessed by use of a comparison between the site-specific metocean conditions and its design conditions, as set out in the RCS approved operations manual;
- ISO 13624‑1 and ISO/TR 13624‑2[1] are referenced for the assessment of the marine drilling riser of mobile floating drilling units. Equivalent alternative methodologies can be used;
- IMCA M 220[5] is referenced for developing an activity specific operating guidelines. Agreed alternative methodologies can be used.
NOTE 1 The scope of ISO 19904‑1 specifically states that its requirements do not apply to mobile units, but the methodologies given for assessing metocean actions can be used.
NOTE 2 RCS rules and the IMO MODU code[4] provide guidance for design and general operation of mobile floating units.

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ISO 18647:2017 gives requirements for the design, fabrication, installation, commissioning and integrity management of modular drilling rigs on offshore fixed platforms.
The modular drilling rig includes some or all of the equipment as follows:
- drilling equipment including a derrick/mast and its controls that can be moved by skidding a drilling support structure;
- drilling support equipment which includes support facilities such as power supply/distribution system;
- mud and cement storage, mixing, monitoring and control equipment.
ISO 18647:2017 is applicable to the modular drilling equipment on offshore structures for the petroleum and natural gas industries, as follows:
- new equipment arranged in a modularized form;
- the equipment contained in several modules, each of which can be lifted and installed on to the platform, however, the equipment may be arranged within the modules as is convenient;
- the modules assembled together offshore for hook up and commissioning;
- intended for long term use on a new fixed offshore structure;
- Intended for temporary use on a number of different offshore platforms.
ISO 18647:2017 is not applicable to drilling equipment
- installed on mobile offshore units, and
- intended primarily for onshore use.
ISO 18647:2017 does not apply to those parts and functions of an offshore platform that are not directly related to drilling.

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This document provides procedures for testing well cements and cement blends for use in the petroleum and natural gas industries in a deepwater environment, or areas with a low seafloor temperature, or areas where low well temperatures exist. This document supplements API RP 10B-3, 2nd edition (2016), the requirements of which are applicable with the exceptions specified in this document. This document excludes the mitigation of shallow water flow in deepwater wells.

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This document specifies requirements and provides recommendations applicable to fixed, floating and grounded concrete offshore structures for the petroleum and natural gas industries and for structures supporting nationally-important power generation, transmission or distribution facility. This document specifically addresses - the design, construction, transportation and installation of new structures, including requirements for in-service inspection and possible removal of structures, - the assessment of structures in service, and - the assessment of structures for reuse at other locations. This document is intended to cover the engineering processes needed for the major engineering disciplines to establish a facility for offshore operation.

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ISO 19905-3 specifies requirements and gives guidance for the site-specific assessment of mobile floating units for use in the petroleum and natural gas industries. It addresses the installed phase, at a specific site, of manned non-evacuated, manned evacuated and unmanned mobile floating units.
ISO 19905-3 addresses mobile floating units that are monohull (e.g. ship-shaped vessels or barges); column-stabilized, commonly referred to as semi-submersibles; or other hull forms (e.g. cylindrical/conical shaped). It is not applicable to tension leg platforms. Stationkeeping can be provided by a mooring system, a thruster assisted mooring system, or dynamic positioning. The function of the unit can be broad, including drilling, floatel, tender assist, etc. In situations where hydrocarbons are being produced, there can be additional requirements.
The requirements of ISO 19905-3 apply to the hull and stationkeeping system for all types of mobile units. The activity specific operating guideline document requirements can be modified to be appropriate to the situation being assessed.
ISO 19905-3 does not address all site considerations, and certain specific locations can require additional assessment.
ISO 19905-3 is applicable only to mobile floating units that are structurally sound and adequately maintained, which is normally demonstrated through holding a valid RCS classification certificate.
ISO 19905-3 does not address design, transportation to and from site, or installation and removal from site.
ISO 19905-3 sets out the requirements for site-specific assessments, but generally relies on other documents to supply the details of how the assessments are to be undertaken. In general:
- ISO 19901‑7 is referenced for the assessment of the stationkeeping system;
- ISO 19904‑1 is referenced to determine the metocean actions on the unit;
- ISO 19906 is referenced for arctic and cold regions;
- the hull structure and airgap are assessed by use of a comparison between the site-specific metocean conditions and its design conditions, as set out in the RCS approved operations manual;
- ISO 13624‑1 and ISO/TR 13624‑2[1] are referenced for the assessment of the marine drilling riser of mobile floating drilling units. Equivalent alternative methodologies can be used;
- IMCA M 220[5] is referenced for developing an activity specific operating guidelines. Agreed alternative methodologies can be used.
NOTE 1 The scope of ISO 19904‑1 specifically states that its requirements do not apply to mobile units, but the methodologies given for assessing metocean actions can be used.
NOTE 2 RCS rules and the IMO MODU code[4] provide guidance for design and general operation of mobile floating units.

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ISO 18647:2017 gives requirements for the design, fabrication, installation, commissioning and integrity management of modular drilling rigs on offshore fixed platforms.
The modular drilling rig includes some or all of the equipment as follows:
- drilling equipment including a derrick/mast and its controls that can be moved by skidding a drilling support structure;
- drilling support equipment which includes support facilities such as power supply/distribution system;
- mud and cement storage, mixing, monitoring and control equipment.
ISO 18647:2017 is applicable to the modular drilling equipment on offshore structures for the petroleum and natural gas industries, as follows:
- new equipment arranged in a modularized form;
- the equipment contained in several modules, each of which can be lifted and installed on to the platform, however, the equipment may be arranged within the modules as is convenient;
- the modules assembled together offshore for hook up and commissioning;
- intended for long term use on a new fixed offshore structure;
- Intended for temporary use on a number of different offshore platforms.
ISO 18647:2017 is not applicable to drilling equipment
- installed on mobile offshore units, and
- intended primarily for onshore use.
ISO 18647:2017 does not apply to those parts and functions of an offshore platform that are not directly related to drilling.

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This document specifies requirements and provides recommendations applicable to fixed, floating and grounded concrete offshore structures for the petroleum and natural gas industries and for structures supporting nationally-important power generation, transmission or distribution facility. This document specifically addresses
— the design, construction, transportation and installation of new structures, including requirements for in-service inspection and possible removal of structures,
— the assessment of structures in service, and
— the assessment of structures for reuse at other locations.
This document is intended to cover the engineering processes needed for the major engineering disciplines to establish a facility for offshore operation.

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This part of ISO 19901 specifies the SIM process engineering requirements and recommendations to be used by an owner for demonstrating the structural fitness-for-service of existing platforms operating offshore. This part of ISO 19901 addresses the platform life-cycle from concept through to decommissioning and/or possible reuse at a different location and is applicable to:
 substructure structural components on compliant bottom founded structures, including fixed platforms, compliant towers, manifolds and structures used offshore as part of an alternative energy concept;
 topsides structural components irrespective of the structural form, including floating facilities and jack-ups.

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This document specifies tests to perform in order to determine the galling tendency, sealing performance and structural integrity of casing and tubing connections. “Casing” and “tubing” apply to the service application and not to the diameter of the pipe. This document covers the testing of connections for the most commonly encountered well conditions. Not all possible service scenarios are included. For example, the presence of a corrosive fluid, which can influence the service performance of a connection, is not considered. This document supplements API RP 5C5:2017, the requirements of which are applicable with the exceptions specified in this document.

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This document specifies requirements and provides recommendations and guidance for the design, construction, transportation, installation and decommissioning of offshore structures related to the activities of the petroleum and natural gas industries in arctic and cold regions. Reference to arctic and cold regions in this document is deemed to include both the Arctic and other locations characterized by low ambient temperatures and the presence or possibility of sea ice, icebergs, icing conditions, persistent snow cover, and/or permafrost. The objective of this document is to ensure that complete structures, including substructures, topsides structures, floating production vessel hulls, foundations and mooring systems, in arctic and cold regions provide an appropriate level of reliability with respect to personnel safety, environmental protection and asset value. Value includes value to the owner, to the industry and to society in general. This document does not contain requirements for the operation, maintenance, service-life inspection or repair of arctic and cold region offshore structures, unless the design strategy imposes specific requirements such as ice management (IM) to reduce ice actions. Provisions for the operation, maintenance, service-life inspection and repair of mobile units are given in ISO 19905-1 and ISO 19905-3, supplemented by the provisions relating to ice actions and IM in this document. This document does not apply to mechanical, process and electrical equipment or any specialized process equipment associated with arctic and cold region offshore operations except in so far as it is necessary for the structure to sustain safely the actions imposed by the installation, housing and operation of such equipment. This document applies to equipment used for the positioning and disconnection of floating structures (see Clause 13).

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This document specifies principles for the structural integrity management (SIM) of offshore structures subjected to known or foreseeable types of actions.
This document specifies requirements and provides recommendations applicable to the following types of fixed steel offshore structures for the petroleum and natural gas industries:
— caissons, free-standing and braced;
— jackets;
— monotowers;
— towers.
This document is applicable to topsides, including but not limited to the main decks, deck legs, topsides modules, crane pedestals, helideck, drilling derrick, skid beams, flare booms, exhaust towers, radio tower, conductor support frames, and lifeboat davits. In addition, it is applicable to compliant bottom founded structures, steel gravity structures, jack-ups, other bottom founded structures and other structures related to offshore structures (e.g. underwater oil storage tanks, bridges and connecting structures), to the extent to which its requirements are relevant.
This document contains requirements for planning and engineering of the following tasks:
a) integrity management data requirements;
b) in-service inspection and integrity management of both new and existing structures;
c) assessment of existing structures;
d) evaluation of structures for reuse at different locations;
e) evaluation of structures for their future removal.

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    153 pages
    English language
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This document specifies requirements and provides recommendations and guidance for the design, construction, transportation, installation and decommissioning of offshore structures related to the activities of the petroleum and natural gas industries in arctic and cold regions. Reference to arctic and cold regions in this document is deemed to include both the Arctic and other locations characterized by low ambient temperatures and the presence or possibility of sea ice, icebergs, icing conditions, persistent snow cover, and/or permafrost.
The objective of this document is to ensure that complete structures, including substructures, topsides structures, floating production vessel hulls, foundations and mooring systems, in arctic and cold regions provide an appropriate level of reliability with respect to personnel safety, environmental protection and asset value. Value includes value to the owner, to the industry and to society in general.
This document does not contain requirements for the operation, maintenance, service-life inspection or repair of arctic and cold region offshore structures, unless the design strategy imposes specific requirements such as ice management (IM) to reduce ice actions.
Provisions for the operation, maintenance, service‐life inspection and repair of mobile units are given in ISO 19905-1 and ISO 19905-3, supplemented by the provisions relating to ice actions and IM in this document.
This document does not apply to mechanical, process and electrical equipment or any specialized process equipment associated with arctic and cold region offshore operations except in so far as it is necessary for the structure to sustain safely the actions imposed by the installation, housing and operation of such equipment. This document applies to equipment used for the positioning and disconnection of floating structures (see Clause 13).

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This document specifies tests to perform in order to determine the galling tendency, sealing performance and structural integrity of casing and tubing connections. "Casing" and "tubing" apply to the service application and not to the diameter of the pipe.
This document covers the testing of connections for the most commonly encountered well conditions. Not all possible service scenarios are included. For example, the presence of a corrosive fluid, which can influence the service performance of a connection, is not considered.
This document supplements API RP 5C5:2017, the requirements of which are applicable with the exceptions specified in this document.

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    12 pages
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This document specifies general requirements and recommendations for the design and assessment of
bottom-founded (fixed) and buoyant (floating) offshore structures.
This document is applicable for all phases of the life of the structure, including:
— successive stages of construction (i.e. fabrication, transportation, and installation),
— service in-place, both during design life and during any life extensions, and
— decommissioning, and removal.
This document contains general requirements and recommendations for both the design of new build
structures and for the structural integrity management and assessment of existing structures.
This document does not apply to subsea and riser systems or pipeline systems.

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    74 pages
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This document specifies requirements and provides recommendations applicable to fixed, floating and grounded concrete offshore structures for the petroleum and natural gas industries and for structures supporting nationally-important power generation, transmission or distribution facility. This document specifically addresses — the design, construction, transportation and installation of new structures, including requirements for in-service inspection and possible removal of structures, — the assessment of structures in service, and — the assessment of structures for reuse at other locations. This document is intended to cover the engineering processes needed for the major engineering disciplines to establish a facility for offshore operation.

  • Standard
    115 pages
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  • Standard
    128 pages
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  • Standard
    128 pages
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This document provides objectives, functional requirements and guidelines for techniques for the
analysis and design of surface process safety systems for offshore installations used for the recovery of
hydrocarbon resources.
It also provides recommendations and requirements on support systems which complement the process
safety systems in reducing risk.
NOTE These are not intended to be exhaustive.
The scope of this document is limited to specifying the methods by which the asset is protected against
loss of containment of hydrocarbon or other hazardous materials.
This document is applicable to
a) fixed offshore structures, and
b) floating offshore production installations
for the petroleum and natural gas industries.
This document is not applicable to mobile offshore units and subsea installations.
NOTE Nevertheless, many of the principles contained in this document can be used as guidance.

  • Standard
    26 pages
    English language
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This document specifies principles for the structural integrity management (SIM) of offshore structures subjected to known or foreseeable types of actions. This document specifies requirements and provides recommendations applicable to the following types of fixed steel offshore structures for the petroleum and natural gas industries: — caissons, free-standing and braced; — jackets; — monotowers; — towers. This document is applicable to topsides, including but not limited to the main decks, deck legs, topsides modules, crane pedestals, helideck, drilling derrick, skid beams, flare booms, exhaust towers, radio tower, conductor support frames, and lifeboat davits. In addition, it is applicable to compliant bottom founded structures, steel gravity structures, jack-ups, other bottom founded structures and other structures related to offshore structures (e.g. underwater oil storage tanks, bridges and connecting structures), to the extent to which its requirements are relevant. This document contains requirements for planning and engineering of the following tasks: a) integrity management data requirements; b) in-service inspection and integrity management of both new and existing structures; c) assessment of existing structures; d) evaluation of structures for reuse at different locations; e) evaluation of structures for their future removal.

  • Standard
    143 pages
    English language
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  • Standard
    158 pages
    French language
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This document specifies requirements and provides recommendations and guidance for the design, construction, transportation, installation and decommissioning of offshore structures related to the activities of the petroleum and natural gas industries in arctic and cold regions. Reference to arctic and cold regions in this document is deemed to include both the Arctic and other locations characterized by low ambient temperatures and the presence or possibility of sea ice, icebergs, icing conditions, persistent snow cover, and/or permafrost. The objective of this document is to ensure that complete structures, including substructures, topsides structures, floating production vessel hulls, foundations and mooring systems, in arctic and cold regions provide an appropriate level of reliability with respect to personnel safety, environmental protection and asset value. Value includes value to the owner, to the industry and to society in general. This document does not contain requirements for the operation, maintenance, service-life inspection or repair of arctic and cold region offshore structures, unless the design strategy imposes specific requirements such as ice management (IM) to reduce ice actions. Provisions for the operation, maintenance, service‐life inspection and repair of mobile units are given in ISO 19905-1 and ISO 19905-3, supplemented by the provisions relating to ice actions and IM in this document. This document does not apply to mechanical, process and electrical equipment or any specialized process equipment associated with arctic and cold region offshore operations except in so far as it is necessary for the structure to sustain safely the actions imposed by the installation, housing and operation of such equipment. This document applies to equipment used for the positioning and disconnection of floating structures (see Clause 13).

  • Standard
    546 pages
    English language
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This document specifies tests to perform in order to determine the galling tendency, sealing performance and structural integrity of casing and tubing connections. "Casing" and "tubing" apply to the service application and not to the diameter of the pipe. This document covers the testing of connections for the most commonly encountered well conditions. Not all possible service scenarios are included. For example, the presence of a corrosive fluid, which can influence the service performance of a connection, is not considered. This document supplements API RP 5C5:2017, the requirements of which are applicable with the exceptions specified in this document.

  • Standard
    4 pages
    English language
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This document specifies general requirements and recommendations for the design and assessment of bottom-founded (fixed) and buoyant (floating) offshore structures.
This document is applicable for all phases of the life of the structure, including:
— successive stages of construction (i.e. fabrication, transportation, and installation),
— service in-place, both during design life and during any life extensions, and
— decommissioning, and removal.
This document contains general requirements and recommendations for both the design of new build structures and for the structural integrity management and assessment of existing structures.
This document does not apply to subsea and riser systems or pipeline systems.

  • Standard
    74 pages
    English language
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This document provides requirements and guidance for the structural design and/or assessment of
floating offshore platforms used by the petroleum and natural gas industries to support the following
functions:
— production;
— storage and/or offloading;
— drilling and production;
— production, storage and offloading;
— drilling, production, storage and offloading.
NOTE 1 Floating offshore platforms are often referred to using a variety of abbreviations, e.g. FPS, FSU, FPSO
(see Clauses 3 and 4), in accordance with their intended mission.
NOTE 2 In this document, the term “floating structure”, sometimes shortened to “structure”, is used as a
generic term to indicate the structural systems of any member of the classes of platforms defined above.
NOTE 3 In some cases, floating platforms are designated as “early production platforms”. This term relates
merely to an asset development strategy. For the purposes of this document, the term “production” includes
“early production”.
This document is not applicable to the structural systems of mobile offshore units (MOUs). These
include, among others, the following:
— floating structures intended primarily to perform drilling and/or well intervention operations
(often referred to as MODUs), even when used for extended well test operations;
— floating structures used for offshore construction operations (e.g. crane barges or pipelay barges),
for temporary or permanent offshore living quarters (floatels), or for transport of equipment or
products (e.g. transportation barges, cargo barges), for which structures reference is made to
relevant recognized classification society (RCS) rules.
This document is applicable to all possible life-cycle stages of the structures defined above, such as:
— design, construction and installation of new structures, including requirements for inspection,
integrity management and future removal,
— structural integrity management covering inspection and assessment of structures in-service, and
— conversion of structures for different use (e.g. a tanker converted to a production platform) or
re‑use at different locations.
The following types of floating structure are explicitly considered within the context of this document:
a) ship-shaped structures and barges;
b) semi-submersibles;
c) spars;
d) shallow-draught cylindrical structures.
In addition to the structural types listed above, this document covers other floating platforms intended
to perform the above functions, consisting of partially submerged buoyant hulls made up of any
combination of plated and space frame components. These other structures can have a great range of
variability in geometry and structural forms (e.g. tension leg platforms) and, therefore, can be only
partly covered by the requirements of this document. In other cases, specific requirements stated in
this document can be found not to apply to all or part of a structure under consideration.
NOTE 4 Requirements for topsides structures are presented in ISO 19901-3.
In the above cases, conformity with this document requires the design to be based upon its underpinning
principles and to achieve a level of safety equivalent, or superior, to the level implicit in it.
NOTE 5 The speed of evolution of offshore technology often far exceeds the pace at which the industry
achieves substantial agreement on innovation in structural concepts, structural shapes or forms, structural
components and associated analysis and design practices, which are continuously refined and enhanced. On the
other hand, International Standards can only capture explicit industry consensus, which requires maturation
and acceptance of new ideas. Consequently, advanced structural concepts can, in some cases, only be partly
covered by the requirements of this document.

  • Standard
    214 pages
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This document provides objectives, functional requirements and guidelines for techniques for the analysis and design of surface process safety systems for offshore installations used for the recovery of hydrocarbon resources.
It also provides recommendations and requirements on support systems which complement the process safety systems in reducing risk.
NOTE These are not intended to be exhaustive.
The scope of this document is limited to specifying the methods by which the asset is protected against loss of containment of hydrocarbon or other hazardous materials.
This document is applicable to
a) fixed offshore structures, and
b) floating offshore production installations
for the petroleum and natural gas industries.
This document is not applicable to mobile offshore units and subsea installations.
NOTE Nevertheless, many of the principles contained in this document can be used as guidance.

  • Standard
    26 pages
    English language
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This document specifies general requirements and recommendations for the design and assessment of bottom-founded (fixed) and buoyant (floating) offshore structures. This document is applicable for all phases of the life of the structure, including: — successive stages of construction (i.e. fabrication, transportation, and installation), — service in-place, both during design life and during any life extensions, and — decommissioning, and removal. This document contains general requirements and recommendations for both the design of new build structures and for the structural integrity management and assessment of existing structures. This document does not apply to subsea and riser systems or pipeline systems.

  • Standard
    64 pages
    English language
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  • Standard
    70 pages
    French language
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This document provides requirements and guidance for the structural design and/or assessment of floating offshore platforms used by the petroleum and natural gas industries to support the following functions:
— production;
— storage and/or offloading;
— drilling and production;
— production, storage and offloading;
— drilling, production, storage and offloading.
NOTE 1 Floating offshore platforms are often referred to using a variety of abbreviations, e.g. FPS, FSU, FPSO (see Clauses 3 and 4), in accordance with their intended mission.
NOTE 2 In this document, the term "floating structure", sometimes shortened to "structure", is used as a generic term to indicate the structural systems of any member of the classes of platforms defined above.
NOTE 3 In some cases, floating platforms are designated as "early production platforms". This term relates merely to an asset development strategy. For the purposes of this document, the term "production" includes "early production".
This document is not applicable to the structural systems of mobile offshore units (MOUs). These include, among others, the following:
— floating structures intended primarily to perform drilling and/or well intervention operations (often referred to as MODUs), even when used for extended well test operations;
— floating structures used for offshore construction operations (e.g. crane barges or pipelay barges), for temporary or permanent offshore living quarters (floatels), or for transport of equipment or products (e.g. transportation barges, cargo barges), for which structures reference is made to relevant recognized classification society (RCS) rules.
This document is applicable to all possible life-cycle stages of the structures defined above, such as:
— design, construction and installation of new structures, including requirements for inspection, integrity management and future removal,
— structural integrity management covering inspection and assessment of structures in-service, and
— conversion of structures for different use (e.g. a tanker converted to a production platform) or re‑use at different locations.
The following types of floating structure are explicitly considered within the context of this document:
a) ship-shaped structures and barges;
b) semi-submersibles;
c) spars;
d) shallow-draught cylindrical structures.
In addition to the structural types listed above, this document covers other floating platforms intended to perform the above functions, consisting of partially submerged buoyant hulls made up of any combination of plated and space frame components. These other structures can have a great range of variability in geometry and structural forms (e.g. tension leg platforms) and, therefore, can be only partly covered by the requirements of this document. In other cases, specific requirements stated in this document can be found not to apply to all or part of a structure under consideration.
NOTE 4 Requirements for topsides structures are presented in ISO 19901-3.
In the above cases, conformity with this document requires the design to be based upon its underpinning principles and to achieve a level of safety equivalent, or superior, to the level implicit in it.
NOTE 5 The speed of evolution of offshore technology often far exceeds the pace at which the industry achieves substantial agreement on innovation in structural concepts, structural shapes or forms, structural components and associated analysis and design practices, w

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This part of EN 10225 specifies requirements for weldable structural steels to be used in the fabrication of fixed offshore structures in the form of sections (e.g. H-, I-, Z-sections, U-channels, angles and tees) excluding hollow sections. The thickness limitation in this standard is up to and including 63 mm.
For steel qualities with mechanical properties in the transverse direction (named xL2O) sections with flange widths smaller than 180 mm and channels with flange smaller widths than 90 mm cannot be ordered.
Greater thicknesses may be agreed, provided the technical requirements of this European Standard are maintained.
The standard is applicable to steels for offshore structures, designed to operate in the offshore sector but not to steels supplied for the fabrication of subsea pipelines, risers, process equipment, process piping and other utilities. It is primarily applicable to the North Sea Sector, but may also be applicable in other areas provided that due consideration is given to local conditions e. g. temperature.
NOTE   There is an Annex E on the prequalification of steels for fixed offshore structures in arctic areas.
Minimum yield strengths up to 460 MPa are specified together with low temperature impact properties at temperatures down to -40 °C.

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This part of EN 10225 specifies requirements for submerged arc welded (SAW) and high frequency welded (HFW) cold formed hollow sections to be used in the fabrication of fixed offshore structures.
The thickness limit for SAWL round hollow sections is up to and including 50,8 mm, for HFW round hollow sections up to and including 25,4 mm and for HFW rectangular hollow sections up to and including 12,5 mm.
Greater thicknesses for SAWL hollow sections may be agreed provided the technical requirements of this European Standard are maintained.
NOTE 1   There is an Annex E about SAWH round hollow sections with thickness limit of 30,0 mm and an Annex F about high strength rectangular HFW hollow sections steel grades S550 to S700 for further information please refer to it.
The standard is applicable to steels for offshore structures, designed to operate in the offshore sector but not to steels supplied for the fabrication of subsea pipelines, risers, process equipment, process piping and other utilities. It is primarily applicable to the North Sea Sector, but may also be applicable in other areas provided that due consideration is given to local conditions e. g. temperature.
NOTE 2   There is an Annex G on the prequalification of steels for fixed offshore structures in arctic areas.
Minimum yield strengths up to 690 MPa are specified together with low temperature impact properties at temperatures down to -40 °C.

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This part of EN 10225 specifies requirements for weldable structural steels to be used in the fabrication of fixed offshore structures in the form of plates.
Following thickness limitations are given in this standard:
-   S355NL1O up to and including 200 mm;
-   S355ML1O, S420ML1O, S460ML1O, S500ML1O up to and including 120 mm;
-   S420QLO, S460QLO, S500QLO, S550QLO, S620QLO, S690QLO up to and including 150 mm.
Greater thicknesses may be agreed, provided the technical requirements of this European Standard are maintained.
The standard is applicable to steels for offshore structures, designed to operate in the offshore sector but not to steels supplied for the fabrication of subsea pipelines, risers, process equipment, process piping and other utilities. It is primarily applicable to the North Sea Sector, but may also be applicable in other areas provided that due consideration is given to local conditions e. g. temperature.
NOTE   There is an Annex F on the prequalification of steels for fixed offshore structures in arctic areas.
Minimum yield strengths up to 690 MPa are specified together with low temperature impact properties at temperatures down to -40 °C.

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This part of EN 10225 specifies requirements for weldable structural steels made of hot finished seamless and high frequency welded hollow sections to be used in the fabrication of fixed offshore structures.
Following thickness limitations are given in this standard:
-   for seamless hollow sections up to and including 65 mm;
-   for HFW hollow sections up to and including 25,4 mm.
Greater thicknesses may be agreed, provided the technical requirements of this European Standard are maintained.
The standard is applicable to steels for offshore structures, designed to operate in the offshore sector but not to steels supplied for the fabrication of subsea pipelines, risers, process equipment, process piping and other utilities. It is primarily applicable to the North Sea Sector, but may also be applicable in other areas provided that due consideration is given to local conditions e. g. temperature.
NOTE   There is an Annex G on the prequalification of steels for fixed offshore structures in arctic areas.
Minimum yield strengths up to 770 MPa are specified together with low temperature impact properties at temperatures down to -40 °C.

  • Standard
    60 pages
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This document provides objectives, functional requirements and guidelines for techniques for the analysis and design of surface process safety systems for offshore installations used for the recovery of hydrocarbon resources. It also provides recommendations and requirements on support systems which complement the process safety systems in reducing risk. NOTE These are not intended to be exhaustive. The scope of this document is limited to specifying the methods by which the asset is protected against loss of containment of hydrocarbon or other hazardous materials. This document is applicable to a) fixed offshore structures, and b) floating offshore production installations for the petroleum and natural gas industries. This document is not applicable to mobile offshore units and subsea installations. NOTE Nevertheless, many of the principles contained in this document can be used as guidance.

  • Standard
    17 pages
    English language
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This document provides requirements and guidance for the structural design and/or assessment of floating offshore platforms used by the petroleum and natural gas industries to support the following functions: — production; — storage and/or offloading; — drilling and production; — production, storage and offloading; — drilling, production, storage and offloading. NOTE 1 Floating offshore platforms are often referred to using a variety of abbreviations, e.g. FPS, FSU, FPSO (see Clauses 3 and 4), in accordance with their intended mission. NOTE 2 In this document, the term "floating structure", sometimes shortened to "structure", is used as a generic term to indicate the structural systems of any member of the classes of platforms defined above. NOTE 3 In some cases, floating platforms are designated as "early production platforms". This term relates merely to an asset development strategy. For the purposes of this document, the term "production" includes "early production". This document is not applicable to the structural systems of mobile offshore units (MOUs). These include, among others, the following: — floating structures intended primarily to perform drilling and/or well intervention operations (often referred to as MODUs), even when used for extended well test operations; — floating structures used for offshore construction operations (e.g. crane barges or pipelay barges), for temporary or permanent offshore living quarters (floatels), or for transport of equipment or products (e.g. transportation barges, cargo barges), for which structures reference is made to relevant recognized classification society (RCS) rules. This document is applicable to all possible life-cycle stages of the structures defined above, such as: — design, construction and installation of new structures, including requirements for inspection, integrity management and future removal, — structural integrity management covering inspection and assessment of structures in-service, and — conversion of structures for different use (e.g. a tanker converted to a production platform) or re‑use at different locations. The following types of floating structure are explicitly considered within the context of this document: a) ship-shaped structures and barges; b) semi-submersibles; c) spars; d) shallow-draught cylindrical structures. In addition to the structural types listed above, this document covers other floating platforms intended to perform the above functions, consisting of partially submerged buoyant hulls made up of any combination of plated and space frame components. These other structures can have a great range of variability in geometry and structural forms (e.g. tension leg platforms) and, therefore, can be only partly covered by the requirements of this document. In other cases, specific requirements stated in this document can be found not to apply to all or part of a structure under consideration. NOTE 4 Requirements for topsides structures are presented in ISO 19901-3. In the above cases, conformity with this document requires the design to be based upon its underpinning principles and to achieve a level of safety equivalent, or superior, to the level implicit in it. NOTE 5 The speed of evolution of offshore technology often far exceeds the pace at which the industry achieves substantial agreement on innovation in structural concepts, structural shapes or forms, structural components and associated analysis and design practices, which are continuously refined and enhanced. On the other hand, International Standards can only capture explicit industry consensus, which requires maturation and acceptance of new ideas. Consequently, advanced structural concepts can, in some cases, only be partly covered by the requirements of this document. This document is applicable to steel floating structures. The principles documented herein are, however, considered to be generally applicable to structures fabricated in materials other

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This document specifies the technical delivery conditions for steel drill-pipes with upset pipe-body
ends and weld-on tool joints for use in drilling and production operations in petroleum and natural gas
industries for three product specification levels (PSL-1, PSL-2 and PSL-3). The requirements for PSL-1
form the basis of this document. The requirements that define different levels of standard technical
requirements for PSL-2 and PSL-3 are in Annex G.
This document covers the following grades of drill-pipe:
— grade E drill-pipe;
— high-strength grades of drill-pipe, grades X, G and S;
— enhanced H2S resistance drill pipe, grades D and F.
A typical drill-pipe configuration is given, showing main elements and lengths (see Figure B.1). The
main dimensions and masses of the grades of drill-pipe are given in both SI units (see Table A.1) and in
USC units (see Table C.1).
This document can also be used for drill-pipe with tool joints not specified by ISO or API standards.
By agreement between purchaser and manufacturer, this document can also be applied to other drillpipe
body and/or tool-joint dimensions. This document lists supplementary requirements that can
optionally be agreed between purchaser and manufacturer, for testing, performance verification and
non-destructive examination (see Annex E).
This document does not consider performance properties, nor performance degradation of the product
when in service.
NOTE 1 In this document, drill-pipe is designated by label 1, label 2, grade of material (E, X, G, S, D and F),
upset type and type of rotary shouldered connection. Designations are used for the purpose of identification in
ordering.
NOTE 2 Reference can be made to ISO 10424-2 or API Spec 7-2 for the detailed requirements for the threading
of drill-pipe tool joints.
NOTE 3 Reference can be made to API RP 7G for the performance properties of the drill-pipe.

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    120 pages
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This document specifies the technical delivery conditions for steel drill-pipes with upset pipe-body ends and weld-on tool joints for use in drilling and production operations in petroleum and natural gas industries for three product specification levels (PSL-1, PSL-2 and PSL-3). The requirements for PSL-1 form the basis of this document. The requirements that define different levels of standard technical requirements for PSL-2 and PSL-3 are in Annex G.
This document covers the following grades of drill-pipe:
— grade E drill-pipe;
— high-strength grades of drill-pipe, grades X, G and S;
— enhanced H2S resistance drill pipe, grades D and F.
A typical drill-pipe configuration is given, showing main elements and lengths (see Figure B.1). The main dimensions and masses of the grades of drill-pipe are given in both SI units (see Table A.1) and in USC units (see Table C.1).
This document can also be used for drill-pipe with tool joints not specified by ISO or API standards.
By agreement between purchaser and manufacturer, this document can also be applied to other drill-pipe body and/or tool-joint dimensions. This document lists supplementary requirements that can optionally be agreed between purchaser and manufacturer, for testing, performance verification and non-destructive examination (see Annex E).
This document does not consider performance properties, nor performance degradation of the product when in service.
NOTE 1 In this document, drill-pipe is designated by label 1, label 2, grade of material (E, X, G, S, D and F), upset type and type of rotary shouldered connection. Designations are used for the purpose of identification in ordering.
NOTE 2 Reference can be made to ISO 10424-2 or API Spec 7-2 for the detailed requirements for the threading of drill-pipe tool joints.
NOTE 3 Reference can be made to API RP 7G for the performance properties of the drill-pipe.

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This document specifies the technical delivery conditions for steel drill-pipes with upset pipe-body ends and weld-on tool joints for use in drilling and production operations in petroleum and natural gas industries for three product specification levels (PSL-1, PSL-2 and PSL-3). The requirements for PSL-1 form the basis of this document. The requirements that define different levels of standard technical requirements for PSL-2 and PSL-3 are in Annex G. This document covers the following grades of drill-pipe: — grade E drill-pipe; — high-strength grades of drill-pipe, grades X, G and S; — enhanced H2S resistance drill pipe, grades D and F. A typical drill-pipe configuration is given, showing main elements and lengths (see Figure B.1). The main dimensions and masses of the grades of drill-pipe are given in both SI units (see Table A.1) and in USC units (see Table C.1). This document can also be used for drill-pipe with tool joints not specified by ISO or API standards. By agreement between purchaser and manufacturer, this document can also be applied to other drill-pipe body and/or tool-joint dimensions. This document lists supplementary requirements that can optionally be agreed between purchaser and manufacturer, for testing, performance verification and non-destructive examination (see Annex E). This document does not consider performance properties, nor performance degradation of the product when in service. NOTE 1 In this document, drill-pipe is designated by label 1, label 2, grade of material (E, X, G, S, D and F), upset type and type of rotary shouldered connection. Designations are used for the purpose of identification in ordering. NOTE 2 Reference can be made to ISO 10424-2 or API Spec 7-2 for the detailed requirements for the threading of drill-pipe tool joints. NOTE 3 Reference can be made to API RP 7G for the performance properties of the drill-pipe.

  • Standard
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