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/TS 35105:2018 provides recommendations for material selection, manufacturing and fabrication requirements, testing and qualification of steel structures and components for offshore and onshore petroleum and natural gas facilities operating in Arctic and cold environments.
ISO/TS 35105:2018 is intended to be used as a supplement to existing standards for steel structures where the particular operating conditions in Arctic regions are not sufficiently addressed.
ISO/TS 35105:2018 gives particular requirements to ensure safe operation with respect to the risk of brittle fracture at low temperatures. These requirements will affect the selection of material grade and design class as well as the technical delivery conditions for steel. They will also affect the fabrication requirements as well as testing and qualification requirements.
ISO/TS 35105:2018 also gives recommendations:
- to mitigate the operational and integrity aspects related to snow and ice accretion on topside structures;
- to take into account the particular Arctic operating conditions in corrosion assessments and requirements for corrosion protection systems;
- for particular operational requirements to ensure safe operation in Arctic regions.
The requirements in this document are applicable to any operating temperatures, but particular requirements related to de-rating (loss of strength) at high temperatures are not addressed. Limitations to the applicable minimum design temperature caused by the capability of the materials' low temperature performance can exist, but are not a limitation for the scope of this document.
As a practical guideline for the use of this document, low temperature is defined as lowest anticipated service temperature (LAST) below ?10 °C.
NOTE For determination of LAST, see 6.3.2.

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ISO 35101:2017 describes the working environment that can be expected when operating oil and gas facilities in Arctic environments/climate. ISO 35101:2017 provides principles and generic guidelines for the design and operation of fixed and floating oil and gas facilities both onshore and offshore.
The aim of ISO 35101:2017 is to ensure optimal health, safety, human performance and decision-making conditions for people working on oil and gas facilities in Arctic conditions.
ISO 35101:2017 applies to the design and operation of new facilities and structures, and to modification of existing facilities for operation in the Arctic environment. This also includes offshore and onshore exploration and accommodation units for such activities.
ISO 35101:2017 is divided into three main parts.
- The first part (Clause 5) describes the general principles and guidelines for risk management.
- The second part (Clause 6) describes the general working environment (working environment hazards found in many workplaces and provides some threshold limit values (TLVs) and design references that can be especially challenging in Arctic conditions.
- The third part (Clause 7 to Clause 9) addresses the climatic conditions expected in the Arctic. Clause 8 describes working environment design and technical solutions, while Clause 9 describes working environment operational requirements for prevention and management of cold-related problems.

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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 35106:2017 specifies requirements and provides recommendations and guidance for the collection, analysis and presentation of relevant physical environmental data for activities of the petroleum and natural gas industries in arctic and cold regions. Activities include design and operations, which involve planning and actual execution.
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, shelf ice, glaciers, icing conditions, persistent snow cover, frozen surfaces of lakes and rivers, localized and rapidly changing weather systems and/or permafrost.
ISO 35106:2017 outlines requirements for a range of different operations that have been or are presently being undertaken and for existing design concepts. This document can also be used for other operations and new design concepts in arctic and cold regions as long as it is recognized that all data requirements are not necessarily addressed.

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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.
NOTE This is addressed in API RP 65.

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ISO 35103:2017 gives requirements, specifications and guidelines to ensure that environmental monitoring in the offshore Arctic region is fit for purpose. The Arctic region includes the territory lying to the North of the Arctic Circle (Latitude 66°33′45.8″). This document can be applied to sub-Arctic locations which experience Arctic-like conditions and contain relevant components of a cold-climate ecosystem.
ISO 35103:2017 is applicable to all Arctic oil and gas operations from licence block acquisition through exploration, engineering design, construction, commissioning, operation, decommissioning and restoration. It covers the offshore or maritime environment, including for the purposes of this document, the fully marine and estuarine waters of the Arctic, whether frozen or ice-free. The environment includes all relevant physical, chemical and biological components. Monitoring methods for onshore (terrestrial) environments are not covered in this document, although onshore environments are included where monitoring is required at onshore locations in relation to an offshore development.
ISO 35103:2017 covers both monitoring of environmental aspects for normal, abnormal and emergency conditions, and monitoring of environmental impacts. It includes monitoring in near-field, far-field, transboundary and regional scales, but does not include global environmental monitoring.

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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 document specifies requirements and gives recommendations on the management of geohazard risks during the pipeline design, construction and operational periods.
This document is applicable to all operators and pipelines (existing and proposed/under construction).
This document applies to onshore gathering and transmission pipelines used in the petroleum and natural gas industries.
NOTE This document is not applicable to piping and pipelines within well-defined plants and facilities, such as pump or compressor stations, processing facilities or refineries. It is assumed that the facility site as a whole will be subject to a separate geohazard assessment to evaluate applicable natural and man-made hazards. Nevertheless, this document can provide useful guidance for assessing the geohazard threat to facilities, including the pipelines within the facility.
This document is applicable to all reasonable and credible natural hazards induced by natural forces and hazards induced by human activity that manifest similarly to natural hazards collectively referred to as "geological hazards" or "geohazards", or through industry as attributed to "natural forces". Geohazards covered by this document include, but are not limited to (not given in order of significance):
— mass wasting processes, including landslides, lateral spreads, rockfalls, debris flows, avalanches, and similar processes whether naturally occurring or anthropogenic;
— land subsidence and/or sinkhole formation, whether naturally occurring such as from dissolution of salt or carbonate rock formations (karst formation) or human caused, such as from underground mining or withdrawal of subsurface fluids such as groundwater and oil and gas;
— seismic hazards, such as ground shaking, fault rupture, liquefaction, flow failures and lateral spreading or associated secondary effects, such as seismically triggered landslides;
— volcanic hazards, such as lahars, pyroclastic flows, lava flows, dam break, and volcanically induced seismicity (excluding ashfall), where such hazards can be reasonably predicted;
— hydrologic processes, such as flooding, vertical scour of river bottoms, channel migration and bank erosion, channel avulsion, rapid lake drainage;
— permafrost/periglacial processes and geothermal effects, such as thermal degradation, frost heave or thaw settlement, thermal erosion, thermokarst;
— surface (overland), trench backfill, or earthwork fill erosion;
— expansion or collapsing processes caused by expansive and collapsible soils, such as glaciomarine clays, collapsible loess, etc.
This document is not applicable to atmospheric/environmental effects, such as the following:
— high winds induced from hurricanes and tornadoes and similar storms, except where such events are reasonably predictable and will induce geohazards such as landslides, erosion, etc.;
— lightning;
— forest or brush fires;
— ashfall from volcanic eruptions.
Furthermore, this document is not applicable to cascading events, where one remote event leads to a chain of events that eventually induces a geohazard near the pipeline. It is only applicable to geohazards that directly affect the pipeline or RoW.

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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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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 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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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.

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This document specifies requirements and gives recommendations on the management of integrity of a pipeline system throughout its life cycle, which includes design, construction, commissioning, operation, maintenance and abandonment.
This document is applicable to offshore pipelines for transporting petroleum and natural gas. It is applicable to rigid steel pipelines. It is not applicable to flexible pipelines, dynamic risers or those constructed from other materials, such as glass-reinforced plastics.
NOTE 1 An offshore pipeline system extends to:
— the first valve, flange or connection above water on platform or subsea mechanical connector with subsea structure (i.e. manifold or dynamic riser);
— the connection point to the offshore installation (i.e. piping manifolds are not included);
— the first valve, flange, connection or isolation joint at a landfall, unless otherwise specified by the onshore legislation.
NOTE 2 The components mentioned above (valve, flange, connection, isolation joint) include also any pup pieces, i.e. the offshore pipeline system extends to the weld beyond the pup piece, see Figure 1.
This document is used for integrity management, which is initiated at the design and construction stage of the pipeline. Where requirements of a design and construction standard (e.g. ISO 13623) are different, the provisions of this document will enhance the design and construction from an integrity perspective.

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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 document specifies requirements and gives recommendations for the mechanical design, material selection, fabrication, inspection, testing and preparation for shipment of shell-and-tube heat exchangers for the petroleum, petrochemical and natural gas industries.
This document supplements API Std 660, 9th edition (2015), the requirements of which are applicable with the exceptions specified in this document.
This document is applicable to the following types of shell-and-tube heat exchangers: heaters, condensers, coolers and reboilers.
This document is not applicable to vacuum-operated steam surface condensers and feed-water heaters.

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This document describes various corrosion under insulation (CUI) environments in refineries and other related industries and environments, and establishes CUI environmental categories including operating temperature ranges from −45 °C to 204 °C for topside and aboveground service only. This document specifies both established and other test methods for the assessment of coatings used for prevention of CUI for each given environment. This document also provides acceptance criteria for each CUI environment.
NOTE The test results and acceptance criteria can be considered an aid in the selection of suitable coating systems. For service or peak temperatures below −45 °C an optional cryogenic test can be incorporated and for over 204 °C testing acceptance criteria can be agreed between interested parties. Additional or other test and acceptance measures are possible, but require particular agreement between the interested parties.
This document covers spray-applied coatings applied on new carbon and austenitic stainless steel for use in CUI service. This document does not cover testing of sacrificial coatings, such as inorganic zinc, as these coatings can be consumed quickly in wet environments. Developing accelerated corrosion testing for what can be continuous wet service with sacrificial coatings is beyond the scope of this document.
"Non-through porosity" thermal spray aluminium coatings with greater than 250 µm dry film thickness can be tested and qualified in accordance with this document. This document does not cover tape and sheet applied products for use in preventing CUI.
This document does not deal with other aspects of coating degradation, such as those caused by abrasion, erosion, ultraviolet degradation or other methods that can exist given specific environment and construction methods.

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This document establishes a procedure for verifying that the manufacturer of special materials for the petroleum, petrochemical and natural gas industries has sufficient competence and experience of the relevant material grades of metal, and the necessary facilities and equipment, to manufacture these materials in the required shapes and sizes with acceptable properties according to the applicable standard, material specification and/or material data sheet specified by the purchaser.
This document is applicable to manufacturers of various materials, product forms and manufacturing processes when specified by the purchaser. This document has been established considering especially, but not exclusively:
a) duplex stainless steel;
b) high alloyed austenitic stainless steel;
c) nickel-based alloys;
d) titanium and its alloys.
This document is also applicable to the processes of induction bending and strain-hardened products.

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This document describes the concept of production assurance within the systems and operations associated with exploration drilling, exploitation, processing and transport of petroleum, petrochemical and natural gas resources. This document covers upstream (including subsea), midstream and downstream facilities, petrochemical and associated activities. It focuses on production assurance of oil and gas production, processing and associated activities and covers the analysis of reliability and maintenance of the components. This includes a variety of business categories and associated systems/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.
This document provides processes and activities, requirements and guidelines for systematic management, effective planning, execution and use of production assurance and reliability technology. This is to achieve cost-effective solutions over the life cycle of an asset development project structured around the following main elements:
— production assurance management for optimum economy of the facility through all of its life cycle phases, while also considering constraints arising from health, safety, environment, and quality;
— planning, execution and implementation of reliability technology;
— application of reliability and maintenance data;
— reliability-based technology development, design and operational improvement.
The IEC 60300-3 series addresses equipment reliability and maintenance performance in general.
This document designates 12 processes, of which seven are defined as core production assurance processes and addressed in this document. The remaining five processes are denoted as interacting processes and are outside the scope of this document. The interaction of the core production assurance processes with these interacting processes, however, is within the scope of this document as the information flow to and from these latter processes is required to ensure that production assurance requirements can be fulfilled.
The only requirement mandated by this document is the establishment and execution of the production assurance programme (PAP). It is important to reflect the PAP in the overall project management in the project for which it applies.
This document recommends that the listed processes and activities be initiated only if they can be considered to add value.

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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 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.

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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.

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This document specifies requirements for the periodic inspection, examination and testing of offshore freight and service containers, built in accordance with ISO 10855‑1, with maximum a 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.
Recommended knowledge and experience of staff responsible for inspection of offshore containers is given in Annex B.
Recommended knowledge and experience of staff responsible for inspection of lifting sets intended for use with offshore containers is given in Annex C.

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This document specifies requirements and provides guidance for the design, testing, installation and commissioning of heating, ventilation, air-conditioning and pressurization systems, and equipment on all offshore production installations for the petroleum and natural gas industries that are
— new or existing,
— normally occupied by personnel or not normally occupied by personnel, and
— fixed or floating but registered as an offshore production installation.
This document is normally applicable to the overall facilities. For installations that can be subject to "Class" or "IMO/MODU Codes & Resolutions", the user is referred to HVAC requirements under these rules and resolutions. When these requirements are less stringent than those being considered for a fixed installation, then it is necessary that this document, i.e. requirements for fixed installations, be utilized.

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ISO 10426-1:2009 specifies requirements and gives recommendations for six classes of well cements, including their chemical and physical requirements and procedures for physical testing.
ISO 10426-1:2009 is applicable to well cement classes A, B, C and D, which are the products obtained by grinding Portland cement clinker and, if needed, calcium sulfate as an interground additive. Processing additives can be used in the manufacture of cement of these classes. Suitable set-modifying agents can be interground or blended during manufacture of class D cement.
ISO 10426-1:2009 is also applicable to well cement classes G and H, which are the products obtained by grinding clinker with no additives other than one or more forms of calcium sulfate, water or chemical additives as required for chromium (VI) reduction.

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ISO 19008:2016 describes the standard cost coding system (SCCS) that classifies costs and quantities related to exploration, development, operation and removal of oil and gas production and processing facilities and to the petroleum, petrochemical and natural gas industry. Upstream, midstream, downstream and petrochemical business categories are included.
The SCCS for coding of costs is applicable to:
- cost estimating;
- actual cost monitoring and reporting;
- collection of final quantities and cost data;
- standardized exchange of cost data among organizations;
- implementation in cost systems.
ISO 19008:2016 is intended for users such as the following:
a) owner/operator/company (individual or grouped entity that is entitled or contributes to operations in the exploitation of oil and gas fields);
b) industry/trade associations;
c) manufacturers/contractors;
d) cost engineering service contractors, cost system providers, benchmarking providers, etc.;
e) authorities/regulatory bodies.
ISO 19008:2016 does not apply to the following:
1) 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 (AFE), billing purposes etc.;
2) specific project breakdown structures (e.g. work breakdown structures, contract breakdown structures, organizational breakdown structure) or asset breakdowns (e.g. TAG/system codes, area/module breakdown structure) which are and will remain unique.
However, this International Standard can provide a basis for the establishment of such specific classification systems.

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The purpose of ISO/TS 17969:2017 is to help members of the oil and gas industry develop, implement, maintain and improve their own competency management systems (CMS) for well operations personnel. ISO/TS 17969:2017 supports competency management general principles which can be applied to any operation within the industry.
The annexes to ISO/TS 17969:2017 list example competence profiles for personnel responsible for well integrity. Annex A includes an example worksheet which can be used in performing a competency assessment, to help record the assessment results versus expectation, as well as the resulting action plan to address any gaps identified.
ISO/TS 17969:2017 is applicable to all operators, service companies and drilling contractors working on wells and well operations.

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ISO 19901-2:2017 contains requirements for defining the seismic design procedures and criteria for offshore structures; guidance on the requirements is included in Annex A. The requirements focus on fixed steel offshore structures and fixed concrete offshore structures. The effects of seismic events on floating structures and partially buoyant structures are briefly discussed. The site-specific assessment of jack-ups in elevated condition is only covered in ISO 19901-2:2017 to the extent that the requirements are applicable.
Only earthquake-induced ground motions are addressed in detail. Other geologically induced hazards such as liquefaction, slope instability, faults, tsunamis, mud volcanoes and shock waves are mentioned and briefly discussed.
The requirements are intended to reduce risks to persons, the environment, and assets to the lowest levels that are reasonably practicable. This intent is achieved by using:
a) seismic design procedures which are dependent on the exposure level of the offshore structure and the expected intensity of seismic events;
b) a two-level seismic design check in which the structure is designed to the ultimate limit state (ULS) for strength and stiffness and then checked to abnormal environmental events or the abnormal limit state (ALS) to ensure that it meets reserve strength and energy dissipation requirements.
Procedures and requirements for a site-specific probabilistic seismic hazard analysis (PSHA) are addressed for offshore structures in high seismic areas and/or with high exposure levels. However, a thorough explanation of PSHA procedures is not included.
Where a simplified design approach is allowed, worldwide offshore maps, which are included in Annex B, show the intensity of ground shaking corresponding to a return period of 1 000 years. In such cases, these maps may be used with corresponding scale factors to determine appropriate seismic actions for the design of a structure.
For design of fixed steel offshore structures, further specific requirements and recommended values of design parameters (e.g. partial action and resistance factors) are included in ISO 19902, while those for fixed concrete offshore structures are contained in ISO 19903. Seismic requirements for floating structures are contained in ISO 19904, for site-specific assessment of jack-ups and other MOUs in ISO 19905 (all parts), for arctic structures in ISO 19906 and for topsides structures in ISO 19901‑3.

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ISO 18797-1:2016 specifies the minimum requirements for materials selection, surface preparation, application, inspection, testing, qualification and acceptance criteria of external coating for steel risers pipes used in the splash zone, their field joints and clamps/guides, using an elastomeric protective coating based on polychloroprene, EPDM or equivalent. This is applicable for new construction and repair of applied pipes before installation. Maintenance requirements and field repairs are covered in ISO 18797-2.
ISO 18797-1:2016 also specifies the requirements for transportation, handling and storage of riser pipes before and after surface preparation and coating application.

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ISO 14692-3:2017 gives guidelines for the design of GRP piping systems. The requirements and recommendations apply to layout dimensions, hydraulic design, structural design, detailing, fire endurance, spread of fire and emissions and control of electrostatic discharge.
This document is intended to be read in conjunction with ISO 14692‑1.

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ISO 14692-2:2017 gives requirements for the qualification and manufacture of GRP piping and fittings in order to enable the purchase of GRP components with known and consistent properties from any source.
It is applicable to qualification procedures, preferred dimensions, quality programmes, component marking and documentation.
ISO 14692-2:2017 is intended to be read in conjunction with ISO 14692‑1.

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ISO 14692-4:2017 gives requirements and recommendations for the fabrication, installation, inspection and maintenance of GRP piping systems for use in oil and natural gas industry processing and utility service applications. The recommendations apply to delivery, inspection, handling, storage, installation, system pressure testing, maintenance and repair.
It is intended to be read in conjunction with ISO 14692‑1.

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ISO 14692-1:2017 defines the applications, pressure rating methodology, the classification of the products according to application, type of joint and resin matrix and the limitations to both the materials of construction and the dimensions. It also lists the terms, definitions and symbols used and provides guidance in the use and interpretation of ISO 14692-2, ISO 14692-3 and ISO 14692-4.
ISO 14692 (all parts) is applicable to GRP piping systems that 1) utilize joints that are capable of restraining axial thrust from internal pressure, temperature change and fluid hydrodynamic forces and 2) have a trapezoidal shape for its design envelope. It is primarily intended for offshore applications on both fixed and floating topsides facilities, but it can also be used for the specification, manufacture, testing and installation of GRP piping systems in other similar applications found onshore, e.g. produced-water, firewater systems and general industrial use.
For floating installations, reference is made to the design, construction and certification standards for the hull or vessel, since these can allow alternative codes and standards for GRP piping associated with marine and/or ballast systems. However, it is recommended that ISO 14692 (all parts) be used for such applications to the maximum degree attainable.
ISO 14692 (all parts) can also be used as the general basis for specification of pipe used for pump caissons, stilling tubes, I-tubes, seawater lift risers and other similar items.

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ISO 24817:2017 gives requirements and recommendations for the qualification and design, installation, testing and inspection for the external application of composite repair systems to corroded or damaged pipework, pipelines, tanks and vessels used in the petroleum, petrochemical and natural gas industries.

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ISO 17781:2017 specifies quality control testing methods and test conditions for the characterization of microstructure in relation to relevant properties in ferritic/austenitic (duplex) stainless steel components supplied in the solution annealed condition and fabrication welds in the as welded condition.
ISO 17781:2017 supplements the relevant product and fabrication standards with respect to destructive testing methods including sampling of test specimens, test conditions and test acceptance criteria to show freedom from deleterious intermetallic phases and precipitates in duplex stainless steels. In addition, this document specifies the documentation of testing and test results by the testing laboratory.
NOTE 1 This document is based upon experience with duplex stainless steels in offshore oil and gas industry applications including topside and subsea hydrocarbon service, sea water service, as well as structural use.
NOTE 2 The austenite spacing is relevant to the susceptibility of duplex stainless steels to hydrogen-induced stress cracking (HISC) in subsea applications where cathodic protection is applied. This falls outside the scope of this document. Reference is made to DNV/GL RP-F112[4].

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ISO 16530-1:2017 is applicable to all wells that are operated by the petroleum and natural gas industry. This document is applicable to any well, or group of wells, regardless of their age, location (including onshore, subsea and offshore wells) or type (e.g. naturally flowing, artificial lift, injection wells).
ISO 16530-1:2017 is intended to assist the petroleum and natural gas industry to effectively manage well integrity during the well life cycle by providing:
- minimum requirements to ensure management of well integrity; and
- recommendations and techniques that well operators can apply in a scalable manner based on a well's specific risk characteristics.
Assuring well integrity comprises two main building blocks: the first is to ensure well integrity during well design and construction, and the second is to manage well integrity throughout the remaining well life thereafter.
This document addresses each stage of the well life cycle, as defined by the six phases in a) to f), and describes the deliverables between each phase within a Well Integrity Management system.
a) The "Basis of Design Phase" identifies the probable safety and environmental exposure to surface and subsurface hazards and risks that can be encountered during the well life cycle. Once identified, these hazards and risks are assessed such that control methods of design and operation can be developed in subsequent phases of the well life cycle.
b) The "Design Phase" identifies the controls that are to be incorporated into the well design, such that appropriate barriers can be established to manage the identified safety and environmental hazards. The design addresses the expected, or forecasted, changes during the well life cycle and ensures that the required barriers in the well's design are based on risk exposure to people and the environment.
c) The "Construction Phase" defines the required or recommended elements to be constructed (including rework/repair) and verification tasks to be performed in order to achieve the intended design. It addresses any variations from the design which require a revalidation against the identified hazards and risks.
d) The "Operational Phase" defines the requirements or recommendations and methods for managing well integrity during operation.
e) The "Intervention Phase" (including work-over) defines the minimum requirements or recommendations for assessing well barriers prior to, and after, any well intervention that involves breaking the established well barrier containment system.
f) The "Abandonment Phase" defines the requirements or recommendations for permanently abandoning a well.
The six phases of the well life cycle, as defined in this Scope, and their interrelationships, are illustrated in Figure 1 in the Introduction.
ISO 16530-1:2017 is not applicable to well control. Well control refers to activities implemented to prevent or mitigate unintentional release of formation fluids from the well to its surroundings during drilling, completion, intervention and well abandonment operations, and involves dynamic elements, i.e. BOPs, mud pumps, mud systems, etc.
ISO 16530-1:2017 is not applicable to wellbore integrity, sometimes referred to as "borehole stability". Wellbore integrity is the capacity of the drilled open hole to maintain its shape and remain intact after having been drilled.

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ISO 17776:2016 describes processes for managing major accident (MA) hazards during the design of offshore oil and gas production installations. It provides requirements and guidance on the development of strategies both to prevent the occurrence of MAs and to limit the possible consequences. It also contains some requirements and guidance on managing MA hazards in operation.
ISO 17776:2016 is applicable to the design of
- fixed offshore structures, and
- floating systems for production, storage and offloading
for the petroleum and natural gas industries.
The scope includes all credible MA hazards with the potential to have a material effect on people, the environment and assets.
This document is intended for the larger projects undertaken to develop new offshore installations. However, the principles are also applicable to small or simple projects or design changes to existing facilities and can also be relevant to onshore production facilities.
Mobile offshore units as defined in this document are excluded, although many of the principles can be used as guidance. The design of subsea facilities are also excluded, though the effects of mobile and subsea facilities are considered if they can lead to major accidents that affect an offshore installation. This document does not cover the construction, commissioning, abandonment or security risks associated with offshore installations.
The decision to apply the requirements and guidance of this document, in full or in part, is intended to be based on an assessment of the likelihood and possible consequences of MA hazards.

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ISO 16440:2016 specifies requirements, including corrosion protection, for the design, fabrication, installation and maintenance of steel-cased pipelines for pipeline transportation systems in the petroleum and natural gas industries in accordance with ISO 13623.
NOTE 1 Steel casings can be used for mechanical protection of pipelines at crossings, such as at roads and railways and the installation of a casing at a highway, railway, or other crossing can be required by the permitting agency or pipeline operator.
NOTE 2 This document does not imply that utilization of casings is mandatory or necessary.
NOTE 3 This document does not imply that cased crossings, whether electrically isolated or electrically shorted, contribute to corrosion of a carrier pipe within a cased crossing. However, cased crossings can adversely affect the integrity of the carrier pipe by shielding cathodic protection (CP) current to the carrier pipe or reducing the CP effectiveness on the carrier pipe in the vicinity of the casing. Their use is not recommended unless required by load considerations, unstable soil conditions, or when their use is dictated by sound engineering practices.

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ISO 14224:2016 provides a comprehensive basis for the collection of reliability and maintenance (RM) data in a standard format for equipment in all facilities and operations within the petroleum, natural gas and petrochemical industries during the operational life cycle of equipment. It describes data collection principles and associated terms and definitions that constitute a "reliability language" that can be useful for communicating operational experience. The failure modes defined in the normative part of this International Standard can be used as a "reliability thesaurus" for various quantitative as well as qualitative applications. This International Standard also describes data quality control and assurance practices to provide guidance for the user.
Standardization of data collection practices facilitates the exchange of information between parties, e.g. plants, owners, manufacturers and contractors. This International Standard establishes requirements that any in-house or commercially available RM data system is required to meet when designed for RM data exchange. Examples, guidelines and principles for the exchange and merging of such RM data are addressed. This International Standard also provides a framework and guidelines for establishing performance objectives and requirements for equipment reliability and availability performance.
Annex A contains a summary of equipment that is covered by this International Standard.
ISO 14224:2016 defines a minimum amount of data that is required to be collected, and it focuses on two main issues:
- data requirements for the categories of data to be collected for use in various analysis methodologies;
- standardized data format to facilitate the exchange of reliability and maintenance data between plants, owners, manufacturers and contractors.
The following main categories of data are to be collected:
a) equipment data, e.g. equipment taxonomy, equipment attributes;
b) failure data, e.g. failure cause, failure consequence;
c) maintenance data, e.g. maintenance action, resources used, maintenance consequence, down time.
NOTE Clause 9 gives further details on data content and data format.
The main areas where such data are used are the following:
1) reliability, e.g. failure events and failure mechanisms;
2) availability/efficiency, e.g. equipment availability, system availability, plant production availability;
3) maintenance, e.g. corrective and preventive maintenance, maintenance plan, maintenance supportability;
4) safety and environment, e.g. equipment failures with adverse consequences for safety and/or environment.
ISO 14224:2016 does not apply to the following:
i. data on (direct) cost issues;
ii. data from laboratory testing and manufacturing (e.g. accelerated lifetime testing), see also 5.2;
iii. complete equipment data sheets (only data seen relevant for assessing the reliability performance are included);
iv. additional on-service data that an operator, on an individual basis, can consider useful for operation and maintenance;
v. methods for analysing and applying RM data (however, principles for how to calculate some basic reliability and maintenance parameters are included in the annexes).

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ISO 19901-4:2016 contains provisions for those aspects of geoscience and foundation engineering that are applicable to a broad range of offshore structures, rather than to a particular structure type. Such aspects are:
- site and soil characterization;
- identification of hazards;
- design and installation of shallow foundations supported by the seabed;
- design and installation of pile foundations;
- soil-structure interaction for auxiliary structures, e.g. subsea production systems, risers and flowlines (guidance given in A.10);
- design of anchors for the stationkeeping systems of floating structures (guidance given in A.11).
Particular requirements for marine soil investigations are detailed in ISO 19901‑8.
Aspects of soil mechanics and foundation engineering that apply equally to offshore and onshore structures are not addressed. The user of this part of ISO 19901 is expected to be familiar with such aspects.
ISO 19901‑4 outlines methods developed primarily for the design of shallow foundations with an embedded length (L) to diameter (D) ratio L/D < 1 (Clause 7) and relatively long and flexible pile foundations with L/D > 10 (Clause 8). This part of ISO 19901 does not apply to intermediate foundations with 1 < L/D < 10. Such intermediate foundations, often known as 'caisson foundations', comprise either shallow foundations with skirts penetrating deeper into the seabed than the width of the foundation, or shorter, more rigid and larger diameter piles than those traditionally used for founding offshore structures. The design of such foundations can require specific analysis methods; it is important that any extrapolation from the design methods described in this part of ISO 19901 to intermediate foundations be treated with care and assessed by a geotechnical specialist.

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ISO 19901:2016 specifies requirements for controlling the weight and centre of gravity (CoG) by means of mass management during the engineering and construction of structures for the offshore environment. The provisions are applicable to offshore projects that include structures of all types (fixed and floating) and materials. These structures can be complete new installations or the modifications to existing installations. Maintaining the weight control of existing installations is not part of the main body of this part of ISO 19901, but some guidance on this is included in the Annex G.
ISO 19901:2016:
- specifies quality requirements for reporting of weights and centres of gravity;
- specifies requirements for weight reporting;
- provides a basis for overall project weight reports or management reports for all weight control classes;
- specifies requirements for weight and load budgets;
- specifies the methods and requirements for the weighing and the determination of weight and CoG of major assemblies;
- specifies requirements for weight information from suppliers, including weighing of equipment and bulk materials for offshore installations.
It can be used:
- as a basis for planning, evaluating and presenting the client's, contractor's or fabricator's weight management and reporting system;
- as a means of refining the structural analysis or model;
- as a contract reference between client, contractor and suppliers;
- as a basis for costing, scheduling or determining suitable fabrication method(s) or location(s).

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ISO 17348:2016 provides guidelines and requirements for material selection of both seamless casing and tubing, and downhole equipment for CO2 gas injection and gas production wells with high pressure and high CO2 content environments [higher than 10 % (molar) of CO2 and 1 MPa CO2 partial pressure]. Oil production wells are not covered in this International Standard. This International Standard only considers materials compatibility with the environment.
Guidance is given for the following:
- corrosion evaluation;
- materials selection;
- corrosion control.
ISO 17348:2016 is aimed at high CO2 content wells, where the threat of low pH and CO2 corrosion is greatest. However, many aspects are equally applicable to environments containing lower CO2 concentrations.
Materials selection is influenced by many factors and synergies and should be performed by either materials or corrosion engineer.

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ISO 17349:2016 contains provisions for design of topside facilities for offshore plants handling CO2-rich streams at high pressures; i.e. CO2 molar concentration above 10 %. The surface systems include usual offshore process unit operations, as shown in Figure 1.
ISO 17349:2016 is applicable only to topside facilities of fixed and floating oil and gas production offshore units up to the last barrier, such as an ESDV. Subsea production systems and Cryogenic CO2 separation are not covered.

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ISO 19905-1:2016 specifies requirements and guidance for the site-specific assessment of independent leg jack‑up units for use in the petroleum and natural gas industries. It addresses:
manned non-evacuated, manned evacuated and unmanned jack‑ups;
the installed phase at a specific site.
To ensure acceptable reliability, the provisions of this part of ISO 19905 form an integrated approach, which is used in its entirety for the site-specific assessment of a jack‑up.
This part of ISO 19905 does not apply specifically to mobile offshore drilling units operating in regions subject to sea ice and icebergs. When assessing a jack-up operating in such areas, it is intended that the assessor supplement the provisions of this part of ISO 19905 with the provisions relating to ice actions and procedures for ice management contained in ISO 19906.
This part of ISO 19905 does not address design, transportation to and from site, or installation and removal from site. However, it is advisable that the assumptions used in the assessment be checked against the as‑installed configuration.
To ensure that the design of the jack‑up is sound and the structure is adequately maintained, this part of ISO 19905 is applicable only to independent leg jack‑ups that either:
- hold a valid classification society certification from a recognized classification society (RCS) throughout the duration of the operation at the specific site subject to assessment; or
- have been verified by an independent competent body to be structurally fit for purpose for elevated situations and are subject to periodic inspection, both to the standards of an RCS.
NOTE 1 An RCS is an International Association of Classification Societies (IACS) member body, meeting the RCS definition given in 3.52.
Jack‑ups that do not comply with this requirement are assessed according to the provisions of ISO 19902, supplemented by methodologies from this part of ISO 19905, where applicable.
NOTE 2 Future revisions of this part of ISO 19905 can be expanded to cover mat-supported jack‑ups.
NOTE 3 Well conductors are a safety-critical element for jack‑up operations. However, the integrity of well conductors is not part of the site-specific assessment process for jack‑ups and is, therefore, not addressed in this part of ISO 19905. Annex A provides references to other publications addressing this topic.
Note 4 RCS rules and the IMO MODU code provide guidance for the design of jack-ups.

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2014-08-21: CEN/BT C068 - derogation from Resolution BT 7/2006 to allow adoption of ISO/TR
2013-08-27: By mutual agreement, ISO/TC 67 and CEN/TC 12 decided to freeze the VA. The ISO/TR will be adopted by CEN/TC 62 once published in ISO.

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ISO 19901-1:2015 gives general requirements for the determination and use of meteorological and oceanographic (metocean) conditions for the design, construction and operation of offshore structures of all types used in the petroleum and natural gas industries.
The requirements are divided into two broad types:
- those that relate to the determination of environmental conditions in general, together with the metocean parameters that are required to adequately describe them;
- those that relate to the characterization and use of metocean parameters for the design, the construction activities or the operation of offshore structures.
The environmental conditions and metocean parameters discussed are:
- 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, and
- normal environmental conditions that are expected to occur frequently during the design service life of the structure.
Metocean parameters 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), and
- the operation of the platform, where appropriate.
NOTE Specific metocean requirements for site-specific assessment of jack-ups are contained in ISO 19905‑1, for arctic offshore structures in ISO 19906 and for topside structures in ISO 19901‑3.

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ISO 19901-8:2014 specifies requirements, and provides recommendations and guidelines for marine soil investigations regarding:
a) objectives, planning and execution of marine soil investigations;
b) deployment of investigation equipment;
c) drilling and logging;
d) in situ testing;
e) sampling;
f) laboratory testing; and
g) reporting.
Rock materials are only covered by ISO 19901-8:2014 to the extent that ordinary marine soil investigation tools can be used, e.g. for chalk, calcareous soils, cemented soils or similar soft rock.
ISO 19901-8:2014 is intended for clients, soil investigation contractors, designers, installation contractors, geotechnical laboratories and public and regulatory authorities concerned with marine soil investigations for any type of offshore and nearshore structures, or geohazard assessment studies, for petroleum and natural gas industries.

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ISO 16961:2015 specifies the minimum 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 systems.
ISO 16961:2015 also provides the minimum requirements for shop performance testing of the coated/lined samples and the criteria for their approval.

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