Jun,30

API SPEC 16F-2004 pdf download

API SPEC 16F-2004 pdf download

API SPEC 16F-2004 pdf download.Specification for Marine Drilling Riser Equipment.
3.25 fill-up line: The line through which fluid is added to the riser annulus. 3.26 fleet angle: In marine riser nomenclature, the fleet angle is the angle between the vertical axis and a riser tensioner line (or hydraulic cylinder rod for direct acting tensioners) at the point where the line (or rod) connects to the telescopic joint (see API RP 16Q). 3.27 flex joint: A steel and elastomer assembly having central through-passage equal to or greater in diameter than the riser bore that may be positioned in the riser string to reduce local bending stresses. 3.28 full length riser joint: A joint of typical length for a particular drilling vessel’s riser storage racks, the derrick V-door size, riser handling equipment capacity or a particular riser purchase. 3.29 handling tool (running tool): A device that joins to the upper end of a riser joint to permit the lifting and lowering of the joint and the assembled riser string in the derrick by the elevators. 3.30 heave: Vessel motion in the vertical direction. 3.31 hot spot stress: See 3.41. 3.32 hydraulic connector: A mechanical connector that is activated hydraulically and connects the BOP Stack to the well- head or the LMRP to the BOP Stack. 3.33 hydraulic supply line: An auxiliary line from the vessel to the subsea BOP Stack that supplies control system operating fluid to the LMRP and the BOP Stack. 3.34 instrumented riser joint: A riser joint equipped with sensors for monitoring parameters such as tension in the riser pipe wall, riser angular offset, annulus fluid temperature and pressure, etc. 3.35 internal yield pressure: As defined in API Bull 5C3. 3.36 jumper line: A flexible section of choke, kill, or auxiliary line that provides a continuous flow around a flex/ball joint while accommodating the angular motion at the flex/ball joint. 3.37 key-seating: The formation of a longitudinal slot in the bore of a riser system component caused by friction wear of the rotating drill string on the riser component.
3.41 local peak stress: Highest stress in the region or component under consideration. The basic characteristic of a peak stress is that it causes no significant distortion and is principally objectionable as a possible initiation site for a fatigue crack. These stresses are highly localized and occur at geometric discontinuities. Sometimes referred to as hot spot stress. 3.42 made-up length: The actual length contributed to a riser string by a made-up riser component (overall component length minus box/pin engagement). 3.43 main tube (riser pipe): Pipe that forms the principal conduit of the riser joint. The riser main tube is the conduit for guiding the drill string and containing the return fluid flow from the well. 3.44 makeup time (riser coupling): Begins when the box and pin are stabbed, ends when the coupling is fully preloaded. 3.45 makeup tool (preload tool): A device used to engage and/or preload coupling members. 3.46 marine drilling riser: A tubular conduit serving as an extension of the well bore from the equipment on the wellhead at the seafloor to a floating drilling rig.
3.48 mud boost line: An auxiliary line which provides supplementary fluid supply from the surface and injects it into the riser at the LMRP to assist in the circulation of drill cuttings up the marine riser, when required. 3.49 nominal stress: Stress calculated using the nominal pipe wall dimensions of the riser at the location of concern. 3.50 pin: The male member of a riser coupling or a choke, kill, or auxiliary line stab assembly. 3.51 preload: Compressive bearing load developed between box and pin members at their interface. This is accomplished by elastic deformation during makeup of the coupling. 3.52 pressure-containing component: A component whose failure to function as intended would cause a release of pres- surized fluid to the environment. 3.53 primary-load-carrying component: Component whose failure would compromise the structural integrity of the marine drilling riser system. Examples are components that carry all or a major part of the tension in the riser. 3.54 protector, box or pin: A cap or cover used to protect the box or pin from damage during storage and handling. 3.55 pup joint: A shorter-than-standard-length riser joint. 3.56 rated load: A nominal applied loading condition used during riser design, analysis and testing based on maximum antic- ipated service loading. 3.57 rated working pressure: The maximum internal pressure equipment is designed to contain and/or control. Working pressure is not to be confused with test pressure. 3.58 riser adapter: Crossover between riser and flex/ball joint. 3.59 riser annulus: The space around the pipe (drill pipe, casing or tubing) suspended in a riser; its outer boundary is the internal surface of the riser pipe. 3.60 riser connector (LMRP connector): A hydraulically operated connector that joins the LMRP to the top of the BOP Stack. 3.61 riser disconnect: The operation of unlatching of the riser connector to separate the riser and LMRP for the BOP Stack.

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