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API RP 17W-2021 pdf free download

API RP 17W-2021 pdf free download.Recommended Practice for Subsea Capping Stacks. Attachmenf bf External Flowi Paths External flow equipment such as jumpers, manifolds, and risers may interface with the subsea capping stack for bullheading and Killing the well or for flowing the incident well” to a containment system! As with the vertical interface to the incident well, this attachment should rely on remote connection technology and may be based on flowline connection or (large-bore) hot stab technologies. In either case, and as with the well attachment, subsea capping stack designs should incorporate industry-standard connections and connectors to allow the maximum amount of flexibility during a subsea capping incident! For tlowline connection points and high-tlow hot stabs provided by subsea equipment vendors that may be proprietary in nature and not easily convertible to a universal connection type, subsea capping stack owners should procure the necessary connection equipment, such as goosenecks, rigid jumpers, pressure caps, hot stabs, and running tools required for tie-back of the subsea capping stack to the intended containment system. Attachmenf to Top of Subsea Cappingi Stack The top interface of the subsea capping stack may connect to installation handling tools and rigging, an additional subsea capping stack, or a containment system. For this reason, the top mandrel interface of the subsea capping stack shall be pressure containing, rated to the full working pressure of the subsea capping stack, and allow for attachment to a subsea hydraulic connector. The attachment interface at the top of the subsea capping stack shall be a user- defined, industry-recognized connection conforming to APT 17D for flange connections and APT 17G for other connections. The functions of this interface may include accepting an additional subsea capping stack, installation handling tools, or attaching flow/pump equipment.
4.4.2 Service Conditions General Service conditions refer to pressure, temperature, material classification, wellbore constituents, and other operating conditions for which the equipment is designed. Equipment shall conform to the API conventions set forth throughout this document. Pressure Ratings Working pressure ratings of all subsea capping stacks shall conform to industry standards set forth by API 17G. Temperature Ratings Subsea capping stacks and their components shall be designed to operate within the temperature classification conventions set forth by API 17D. Typically, the minimum temperature is the lowest ambient temperature that the equipment may be subjected to during operation, transportation, and preservation while the maximum temperature is encountered during flowing conditions. Unless other requirements are identified, the minimum classification for pressure-containing and pressure- controlling materials should be temperature classification UC-18 C C F)to 121 C (250 F). The design shal address the effects of thermal expansion and contraction from temperature changes that the equipment can experience in service. The effects of Joule-Thompson cooling and imposed flowline heating or heat retention (insulation) shall also be considered. Thermal analysis can be used to establish component temperature-operating requirements. API 17G provides information for design and rating of equipment for use at elevated temperatures. Service Life A subsea capping stack should be designed for two years of installed subsea service, which includes six months of continuous flowing service (Category 2 only), and a minimum of 20 years of land-based preservation and maintenance service. Life estimation and aging of components and materials within the subsea capping stack assembly shall be based on API 17D. Where available, the manufacturer may base the life estimation on known component failure and deterioration data (mean time between failure and shelf life). The manufacturer shall define additional applicable penewal of design verification and shelf Tife replacement schedules and demonstrate that these schedules can be correlated with the intended service life and/or operating conditions in accordance with the purchaser requirements. Life estimation shall account for proper preservation, storage, maintenance, periodic renewal of design verification, and testing and replacement routines. Selection of elastomeric and thermoplastic materials shall take into account the potential deterioration under surface UV light and dry rot conditions. Cathodic and Corrosion Protection and Coatings External corrosion control for equipment shall be provided in the design by appropriate materials selection, coating systems, and cathodic protection. Electric continuity tests shall be performed in accordance with API 17D for cathodic and corrosion protection and coatings. It is a recommended practice to design for accessibility to maintain the coating and cathodic protection systems/methods given the possible long-term land-based storage method.

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