API RP 64:2001 pdf download
API RP 64:2001 pdf download.Recommended Practice for Diverter Systems Equipment and Operations.
3.1.54 hydrostatic head: The true vertical length of fluid column, normally in ft.
3.1.55 hydrostatic pressure: The pressure that exists at any point in the welibore due to the weight of the vertical column of fluid above that point.
3.1.56 inner barrel: The part of a telescopic slip joint on a marine riser that is attached to the flexible joint beneath the diverter.
3.1.57 insert-type packer: A diverter element that uses inserts designed to close and seal on specific ranges of pipe diameter.
3.1.58 inside blowout preventer: A device that can he installed in the drill string that acts as a check valve allowing drilling fluid to he circulated down the string hut prevents back flow.
3.1.59 integral valve: A valve embodied in the diverter unit that operates integrally with the annular sealing device.
3.1 .60 interlock: An arrangement of control system functions designed to require the actuation of one function as a prerequisite to actuate another.
3.1.61 kelly: The uppermost component of the drill string; the kelly is an extra-heavy joint of pipe with flat or fluted sides that is free to move vertically through a “kelly hushing” in the rotary table; the kelly bushing imparts torque to the kelly and thereby the drill string is rotated.
3.1.62 kick: An influx of gas, oil, or other well fluids, which if not controlled, can result in a blowout.
3.1.63 kill drilling fluid density: The unit weight. e.g..
pounds per gallon (lb/gal), selected for the fluid to he used to contain a kicking formation.
3.1.64 knife valve: A valve using a portal plate or blade to facilitate open and close operation; different from a gate valve in that the bonnet area is open, i.e., not sealed.
3.1.65 locking mechanism: A support or restraint device.
3.1.66 lost circulation (lost returns): The loss of whole drilling fluid to the wellhore.
3.1.67 marine riser system: The extension of the well- bore from the subsea BOP stack to the floating drilling vessel which provides for fluid returns to the drilling vessel, supports the choke, kill, and control lines, guides tools into the well, and serves as a running string for the BOP stack.
3.1.68 moored vessels: Offshore floating drilling vessels. which rely on anchors, chain, and mooring lines extended to the ocean floor to keep the vessel at a constant location relative to the ocean floor.
3.1.69 mud/gas separator: A device that separates entrained gas from the drilling fluid system.
3.1.70 mud line: The floor of a body of water such as an ocean, lake, bay or swamp.
3.1.71 offshore platforms: Permanently installed bottom-supportedJconnected, offshore structures equipped with drilling and/or production equipment for drilling and/or development of offshore oil and gas reservoirs.
3.1.72 outer barrel: The part of a telescopic slip joint on a marine riser that is attached to tensioner lines. Tension is transferred through the outer barrel into the riser.
3.1.73 packing element: The annular sealing device in an annular BOP or diverter. Also, the elastomer packing element used in valves or lubricators to eftèct a seal.
3.1.74 pack-off or stripper: A device with a rubber!
elastomer packing element that depends on pressure below the packing to effect a seal in the annulus. Used primarily to run or pull pipe under low or moderate pressures. This device is not dependable for service under high differential pressures.
3.1.75 pressure equalization valve (dump valve):A
device used to control bottom-riser annulus pressure by establishing direct communication with the sea.
3.1.76 pressure regulator: A control system component that permits attenuation of control system supply pressure to a satisfactory pressure level to operate components downstream.
3.1.77 primary well control: Prevention of formation fluid flow by maintaining a hydrostatic pressure equal to or greater than formation pressure.
3.1.78 remote controlled valve: A valve that is controlled from a remote location.
3.1.79 riser spider: Equipment used to support the marine riser while it is being run or retrieved.
3.1.80 rotating head or rotating drilling head: A
rotating, low pressure sealing device used in drilling operations utilizing air, gas, or foam (or any other drilling fluid whose hydrostatic pressure is less than the formation pressure) to seal around the drill stem above the top of the BOP stack.
3.1.81 rotating stripper head: A sealing device installed above the BOP and used to close the annular space about the drill pipe or kelly when pulling or running pipe under pressure.
3.1.82 rotary table: A device through which passes the hit and drill string and that transmits rotational action to the kelly.
