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API RP 59-2006 pdf free download

API RP 59-2006 pdf free download.Recommended Practice for Well Control Operations.
1 Scope 1.1 PURPOSE The purpose of these recommended practices is to provide information that can serve as a voluntary industry guide for safe well control operations. This publication is designed to serve as a direct field aid in well control and as a technical source for teaching well control principles. This publication establishes recommended operations to retain pressure con- trol of the well under pre-kick conditions and recommended practices to be utilized during a kick. It serves as a companion to API RP 53, Recommended Practice for Blowout Preven- tion Equipment Systems for Drilling Wells and API RP 64 Recommended Practice for Diverter Systems Equipment and Operations (reader should check for the latest edition). RP 53 establishes recommended practices for the installation and testing of equipment for the anticipated well conditions and service and RP 64 establishes recommended practices for installation, testing, and operation of diverters systems and discusses the special circumstances of uncontrolled flow from shallow gas formations. 1.2 BOP INSTALLATIONS The recommended practices are separated into two main systems: 1. Blowout preventers (BOPs) at the surface within reach and sight of the driller or well service unit operator, and 2. BOPs installed on the seafloor with relatively long choke and kill lines. In this publication, sections have been prepared to establish practices and procedures pertaining to both surface BOP installations and subsea BOP installations. The delineation between surface BOP installations and subsea BOP installa- tions is mainly on an exception basis, and the recommenda- tions made for surface installations apply to subsea installations unless exceptions are stated. The recommended practices can apply to drilling, well service unit, and coiled well control worksheets for surface and subsea BOP installa- tions are included in Appendix B.
3.1.5 annulus friction pressure: Circulating pressure loss inherent in the annulus between the drill string and cas- ing or open hole. 3.1.6 backpressure (casing pressure, choke pres- sure): The pressure existing at the surface on the casing side of the drill string/annulus flow system. 3.1.7 barite plug: A settled volume of barite particles from a barite slurry placed in the well bore to seal off a pres- sured zone. 3.1.8 barite slurry: A mixture of barium sulfate, chemi- cals, and water of a unit density between 18 and 22 pounds per gallon (lb/gal). 3.1.9 belching: A slang term to denote flowing by heads. 3.1.10 bell nipple: A piece of pipe, with inside diameter equal to or greater than the BOP bore, connected to the top of the BOP or marine riser with a side outlet to direct the drilling fluid returns to the shale shaker or pit. Usually has a second side outlet for the fill-up line connection. 3.1.11 bleeding: Controlled release of fluids from a closed and pressured system in order to reduce the pressure.
3.1.98 Remotely Operated Vehicle (ROV): An unmanned vehicle for offshore subsea use. 3.1.99 replacement: The process whereby a volume of fluid equal to the volume of steel in tubulars and tools with- drawn from the well bore is returned to the well bore. 3.1.100 rotating head or rotating drilling head: A rotating, low pressure sealing device used in drilling opera- tions utilizing air, gas, or foam (or any other drilling fluid whose hydrostatic pressure is less than the formation pres- sure) to seal around the drill stem above the top of the BOP stack. 3.1.101 rotating stripper head: A sealing device installed above the BOPs and used to close the annular space about the drill pipe or kelly when pulling or running pipe under pressure. 3.1.102 rotary table: A device through which passes the bit and drill string and that transmits rotational action to the kelly. 3.1.103 safety factor: In the context of this publication, an incremental increase in drilling fluid density beyond the drilling fluid density indicated by calculations to be needed to contain a kicking formation. 3.1.104 saltwater flow: An influx of formation saltwater into the well bore. 3.1.105 shale shaker: A vibrating screen that removes relatively large size cuttings from the drilling fluid returns. 3.1.106 shear rams: BOP rams with a built-in cutting edge that will shear tubulars that may be in the hole. 3.1.107 soft close-in: To Close-in a well by closing a BOP with the choke and choke line valve open, then closing the choke while monitoring the casing pressure gauge for maximum allowable casing pressure.

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