API RP 53:1997 pdf download

API RP 53:1997 pdf download.Recommended Practices for Blowout Prevention Equipment Systems for Drilling Wells.
3.1.39 full bore valve: A valve with unobstructed flow area dimension equal to or greater than the nominal connection sue.
3.1.40 function test: Closing and opening (cycling) equipment to verify operability.
3.1.41 gate valve: A vaive that employs a sliding gate to open or close the flow passage. The valve may or may not be lull opening.
3.1.42 hang off: An action whereby that portion of the drill string below the ram BOP remains in the holc supported by a tool joint resting atop the closed pipe rams.
3.1.43 hydrogen sulfide (H2S): A highly toxic, flammable. corrosive gas sometimes cncountered in hydrocarbon bearing formations.
3.1.44 hydrogen sulfide equipment service: Equipment designed to resist corrosion and hydrogen cmbrittlemeni caused by exposure to hydrogen sulfide (H2S).
3.1.45 hydrostatic head: The pressure that exists at any point in the welibore due to the weight of the column of fluid above that point.
3.1.46 insert type (packer) diverter: A diverter assembly whose body does not require disassembly to utilize interchangeable packing clcmcnts that are specifically sized for the pipe diameter in use in the hole.
3.1.47 inside blowout preventer (BOP): A device that can he installed in the drill string that acts as a check valve allowing drilling fluid to be circulated down the string but prevents hack flow.
3.1.48 integral valve: A valve cmbodicd in the diverter unit that operates integrally with the annular sealing device.
3.1.49 interlock: An arrangement of control system functions designed to require the actuation of one function as a prerequisite to actuate another function. Also referred to as sequencing.
3.1.50 kely cock: A valve immediately above the kelly that can be closed to confine pressures inside the drill sting.
3.1.51 kelly valve, lower: An essentially full-opening valve installed immediately below the kelly, with outside diameter equal to the drill pipe tool joint outside diameter. This valve can be closed under pressure to remove the kelly and can be stripped into the hole for snubbing operations.
3.1.54 lost returns: Loss of drilling fluid into the formation resulting in a decrease in pit volume.
3.1.55 minimum internal yield pressure: The lowest pressure at which pennanent deformation will occur.
3.1.56 opening ratio: The ratio of the well pressure to the pressure required to open the BOP
3.1.57 overburden: The pressure on a formation due to the weight of the earth material above that formation. For practical purposes, this pressure can be estimated at I psi/ft of depth.
3.1.58 packoff or stripper: A device with an ebstomer packing element that depends on pressure below the packing to effect a seal in the annulus. This device is used primanly to run or pull pipe under low or moderate pressures. This device is not normally considered dependable for service under high differential pressures.
3.1.59 pipe rams: Rams whose ends are contoured to seal around pipe to close the annular space. Unless special rams accommodating several pipe sizes are used, separate rams are necessary for each size (outside diameter) pipe in use.
3.1.60 pit volume indicator: A device installed in the drilling fluid tank to register the fluid level in the tank.
3.1.61 pit volume totalizer: A device that combines all of the individual pit volume indicators and registers the total drilling fluid vohime in the various tanks.
3.1.62 plug valve: A valve whose mechanism consists of a plug with a hole through it on the same axis as the direction of fluid flow. Thrning the plug 90 degrees opens or closes the valve. The valve may or may not be full.opcning.