This document provides subsea capping stack recommended practices for design, manufacture, and use. The document applies to the construction of new subsea capping stacks. The document can aid in generating a basis of design (BOD) document, as well as preservation, transportation, maintenance, testing documents, and operating instructions.

This document does not address procedures and equipment downstream of the capping stack. All equipment and operations downstream of the subsea capping stack are considered part of a containment system and are not within the scope of this recommended practice.

Annex A contains a discussion of possible subsea capping contingency procedures. Annex B contains example procedures for deployment, well shut-in, recovery, and storage of a subsea capping stack.

Recommended Practice 17W is available for purchase at American Petroleum Institute (API) website www.api.org   

This recommended practice is based on global industry best practices and serves as a guide for those who are concerned with the design and construction of new fixed offshore platforms and for the relocation of existing platforms used for the drilling, development, production, and storage of hydrocarbons in offshore areas.

This standard is available for purchase at the API Publication Store:https://www.apiwebstore.org/standards/2A-WSD 

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, etc. (see Clauses 3 and 4), in accordance with their intended mission.

NOTE 2 In this standard, 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 International Standard, the term “production” includes “early production”.

Its requirements do not apply to the structural systems of mobile offshore units (MOUs). These include, among others:

⎯ 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.

Its requirements are 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 reuse at different locations.

The following types of floating structure are explicitly considered within the context of this standard:

a) monohulls (ship-shaped structures and barges);

b) semi-submersibles;

c) spars.

In addition to the structural types listed above, this standard 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 and used in conjunction with the stationkeeping systems covered in API 2SK. These other structures can have a great range of variability in geometry and structural forms and, therefore, can be only partly covered by the requirements of this standard. In other cases, specific requirements stated in this standard can be found not to apply to all or part of a structure under design.

In all the above cases, conformity with this standard will require that the design is based upon its underpinning principles and achieves a level of safety equivalent, or superior, to the level implicit in it.

NOTE 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 provisions of standard.

This standard is applicable to steel floating structures. The principles documented herein are, however, considered to be generally applicable to structures fabricated in materials other than steel.

Similarly, while this document is directly applicable to oil and gas producing platforms operating at ambient temperature, the principles documented herein are considered to be generally applicable to structures used in conjunction with cryogenic processes, such as floating liquefied gas (FLNG) plants, with the exception of the aspects related to handling and storage of cryogenic liquids.

The structural design and fabrication of the drilling and production modules supported by a floating structure can be carried out in accordance with API 2A–WSD, 21^st Edition, Errata and Supplement 3.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

API 17A provides general requirements and recommendations for the development of subsea production systems, from the design phase to decommissioning and abandonment. This document also references to other API 17-series documents as well as various other relevant industry documents.

The complete subsea production system comprises several subsystems necessary to produce hydrocarbons from one or more subsea wells and transfer them to a given processing facility located offshore (fixed, floating, or subsea) or onshore, or to inject water/gas through subsea wells.

This document, given its broad scope, has a systems engineering section. The purpose of this section is to help ensure consistency across the various subsystems.

If requirements as stated in this document are in conflict with, or are inconsistent with, requirements as stated in other API 17-series documents, then the specific requirements in the subsystems series document(s) take precedence.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

This recommended practice (RP) aims to provide operators, contractors and suppliers with guidance on the management and application of reliability and integrity management (RIM) engineering techniques in subsea projects and operations within their scope of work and supply. It is applicable to:

— standard and nonstandard equipment (within the scope of API 17A);

— new field developments, further development of existing fields and field upgrades;

— all life cycle phases from feasibility through design, manufacture, and operation to decommissioning.

NOTE API 18LCM ^[1] gives additional guidance on general requirements for life cycle management of equipment.

This RP is not intended to replace individual company processes, procedures, document nomenclature, or numbering; it is a guide. For example, this RP does not prescribe the use of any specific equipment or process. It does not recommend any actions, beyond good engineering practice. However, this RP may be used to enhance existing processes, if deemed appropriate.

This standard can be purchase via the American Petroleum Institute (API) website www.api.org 

This part provides standardized calculation methods for the determination of meter factors under defined conditions, regardless of the point of origin or destination or units of

measure required by governmental customs or statute. The criteria contained here will allow different entities using various computer languages on different computer hardware (or by manual calculations) to arrive at identical results using the same standardized input data. 

This document also specifies the equations for computing correction factors, including the calculation sequence, discrimination levels, and rules for rounding to be employed in the calculations. No deviations from these specified equations are permitted, since the intent of this document is to establish a rigorous standard.

This standard can be purchase via the American Petroleum Institute (API) webstore: https://www.apiwebstore.org/standards/12_2_4  

This part of ISO/IEC 9314 specifies the Media access control (MAC) , the middle sublayer of the data link layer (DLL) for fiber distributed data interface (FDDI) .FDDI (ISO/IEC 9314) provides a high -bandwidth (100 Mbit/s).general - purpose interconnection among information processing systems, subsystems and peripheral equipment , using fiber optics or other transmission media. FDDI can be configured to support a sustained data transfer rate of at least 80 Mbit/s (10 Mbytes/s). FDDI provides connectivity for many nodes distributed over distances of many kilometers in extent . Certain default parameter values for FDDDI (e.g. timer settings) are calculated on the basis of up to 1000 transmission links or up to 200 km total fiber path length (typically corresponding to 5000 nodes and 100 km of dual fiber cable, respectively), however, the FDDI protocols can support much larger networks by increasing these parameter values.

This part of ISO/IEC 18026 provides an overview of different techniques of security gateways, of components and of different types of security gateway architectures, it also provides guidlines for selection and configuration of security gateways.

This part of ISO/IEC 20000 defines the requirements for a service provider to deliver managed services of an acceptable quality for its customers

This part of ISO/IEC 20000 represents an industry consensus on quality standards for IT service management processes . These service management processes deliver the best possible service to meet a customer's business needs within agreed resource levels, i.e. Service that is professional cost-effective and with risks which are understood and managed.