A device placed in a choke line that regulates the flow through the choke. flow depends on the size of the opening in the bean; the larger the opening, the greater the flow.

A choke in which the orifice size must be changed to change the rate of flow through the choke.

The valve on the choke and flow line that is nearest to the preventer assembly. its purpose is to stop the flow through the choke and flow line.

1. a pipe attached to the blowout preventer stack out of which kick fluids and mud can be pumped to the choke manifold when a blowout preventer is closed in on a kick.
2. a high-pressure pipe leading from an outlet on the bop stack to the backpressure choke and associated manifold. during well-control operations, the fluid under [...]

An arrangement of piping and special valves, called chokes. in drilling, mud is circulated through a choke manifold when the blowout preventers are closed. in well testing, a choke manifold attached to the wellhead allows flow and pressure control for test components downstream.

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A tubing safety valve.

A bottomhole choke run on wireline and landed in a nipple profile in the tubing string.

A set of controls, usually placed on the rig floor, that is manipulated to control the amount of drilling fluid being circulated through the choke manifold. this procedure is necessary when a kick is being circulated out of a well. see choke manifold.

An extension from the blowout preventer assembly used to direct control the flow of well fluids from the annulus to the choke.

A device with a restricted opening placed in the lower end of the tubing to control the rate of flow. see choke.

A choke, used to regulate flow of fluid from a well. different sizes of beans are used for different producing rates.

A fitting placed in the blowout preventer stack to provide space between preventers for facilitating stripping operations, to permit attachment of choke and kill lines, and for localizing possible erosion by fluid flow to the spool instead of to the more expensive pieces of equipment.

A well is considered “stabilized” when, in the case of a flowing well, the rate of production through a given size of choke remains constant, or, in the case of pumping well, when the fluid column within the well remains constant in height.

A storm choke