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A blowout preventer (BOP) (pronounced B-O-P) [1] is a specialized valve or similar mechanical device, used to seal, control and monitor oil and gas wells to prevent blowouts, the uncontrolled release of crude oil or natural gas from a well. They are usually installed in stacks of other valves.
The BOP valve affixed to the wellhead could be closed in the event of drilling into a high pressure zone, and the well fluids contained. Well control techniques could be used to regain control of the well. As the technology developed, blowout preventers became standard equipment, and gushers became a thing of the past.
In general well heads are five nominal ratings of wellheads: 2, 3, 5, 10 and 15 (×1000) psi working pressure. They have an operating temperature range of −50 to +250 degrees Fahrenheit. They are used in conjunction with ring type seal gaskets. In general the yield strength of the materials range from 36000 to 75000 psi.
The Cameron ram-type blowout preventer was the first successful blowout preventer (BOP) for oil wells. It was developed by James S. Abercrombie and Harry S. Cameron in 1922. [1] [2] The device was issued U.S. patent 1,569,247 on January 12, 1926. [3] The blowout preventer was designated as a Mechanical Engineering Landmark in 2003. [1] [2] [4]
There is a variety of manufacturers of these gauges, but most utilize either a three-valve or a five-valve design to test the RPZD in different ways. In the UK , [ 6 ] Illinois, New York , [ 7 ] Texas , [ 8 ] and Missouri ( RsMO 10c60-11 ), the RPZD valve must be tested at least every 12 months by an accredited tester.
A rupture disc (burst) Pressure-effect acting at a rupture disc A rupture disc, also known as a pressure safety disc, burst disc, bursting disc, or burst diaphragm, is a non-reclosing pressure relief safety device that, in most uses, protects a pressure vessel, equipment or system from overpressurization or potentially damaging vacuum conditions.
Casing heads are the primary interface for the surface pressure control equipment, for example blowout preventers (for well drilling) or the Christmas tree (for well production). The casing head, when installed, is typically tested to very strict pressure and leak-off parameters to insure viability under blowout conditions, before any surface ...
CITHP – closed-in tubing head pressure (tubing head pressure when the well is shut in) CIV – chemical injection valve; CK – choke (a restriction in a flowline or a system, usually referring to a production choke during a test or the choke in the well control system) CL – core log; CLG – core log and graph; CM – choke module