A flow control module includes an inlet hub coupled to a first flow passage having a first flow bore, a flow meter, and a choke disposed in a second flow passage having a second flow bore, where the second flow passage is coupled to a distal end of the first flow passage. The flow meter is associated with the first flow bore and positioned for top-down fluid flow. The flow control module also includes an outlet hub coupled to a distal end of the second flow passage, where the outlet hub faces in a different direction from the inlet hub.

A subsea Christmas tree includes a valve block having a generally axially extending production bore, a first production branch which extends generally laterally through the valve block from the production bore to a side of the valve block, and a second production branch which extends generally laterally through the valve block from a first side of the valve block to a second side of the valve block. The first production branch has a first end which is connected to the flow bore and a second end which is located on the side of the valve block, and the second production branch has a first end which is located on the first side of the valve block and a second end which is located on the second side of the valve block. At least one flow component is connected to the valve block and includes, a first end in fluid communication with the second end of the first production branch and a second end in fluid communication with the first end of the second production branch. An outlet hub which is connected to or formed integrally with the valve block is connected to the second end of the second production branch. During the production mode of operation of the Christmas tree, production fluid is directed through the valve block through the first production branch to the flow component and then through the valve block through the second production branch to the outlet hub.

A fluid conduit communicates fluid between a zipper leg and an oil and gas wellhead. The fluid conduit may be completely flexible, completely rigid, or partially flexible and partially rigid. The fluid conduit is coupled to the wellhead via a first flow block. The first flow block may include a first downwardly angled surface through which a first downwardly angled flow passage extends and to which a first end portion of the fluid conduit is connected. Similarly, the fluid conduit is coupled to the zipper leg via a second flow block. The second flow block may include a second downwardly angled surface through which a second downwardly angled flow passage extends and to which the fluid conduit is connected.

An oilwell choke can include a choke body having an inlet and an outlet, a seat, a gate configured to optionally sealingly engage the seat, and an at least partially curved choke profile. A gate can include an at least partially curved gate profile and a seat can include an at least partially curved seat profile. A choke profile can have one or more radiuses of curvature. At least a portion of a choke profile can be elliptical. An oilwell choke can include a secondary closure, which can include an annular tongue configured to sealingly engage an annular groove.

A pressure balanced well flow control system includes a pressure balanced variable orifice flow control having a controlled flow inlet in fluid communication with a subterranean well and a balance pressure inlet in fluid communication with an outlet end of a fluid pressure isolator. An inlet end of the fluid pressure isolator is in fluid communication with the subterranean well.

Provided is a retrievable choke insert. The retrievable choke insert, in one aspect, includes an outer housing including a central bore extending axially through the outer housing, an open end, a closed end, and one or more outer housing openings extending through an outer housing sidewall thickness, and a bore flow management actuator disposed in the central bore, the bore flow management actuator having one or more bore flow management openings extending through a bore flow management actuator sidewall thickness, the bore flow management actuator operable to convey subsurface production fluids there through. The retrievable choke insert, in accordance with this aspect, further includes one or more choke insert magnets coupled to the bore flow management actuator, the one or more choke insert magnets configured to magnetically couple with one or more landing nipple magnets of a choke landing nipple to slide the bore flow management actuator and move the one or more bore flow management openings relative to the one or more outer housing openings to control an amount of the subsurface production fluid entering the bore flow management actuator.

A choke valve system operable to obtain sand production measurements from a sand production sensor, compare the sand production measurements to a target sand production range for a current setting of a choke valve, and, in response to determining that the sand production measurements are outside of the target sand production range, adjust the setting of the choke valve in an effort to bring the sand production of the well into a target sand production range, and generate an alert regarding the out of range sand production measurements and the corresponding adjustment of the choke valve.

A cage for a choke valve assembly and method for using the same is provided. The cage includes one or more teardrop shaped orifices for the manipulation of fluid flow through the choke valve assembly.

Methods and systems including a wellbore having a pipe string extending through a wellhead and into the wellbore, wherein an annulus is formed between the pipe string and the wellbore, an isolation device that closes the wellbore in a closed pressure loop, a choke line in fluid communication with an interior of the pipe string through an outlet port of the wellhead, a choke valve fluidly coupled to the outlet port of the wellhead, wherein the choke valve is manipulable to control fluid flow through the choke line, and a crossover tool in the wellbore to divert incoming fluid from the interior of the pipe string to the annulus.

A wellhead assembly of a well system for installation in a wellbore, the wellhead assembly having a longitudinal axis and including a wellhead housing including a central passage defined by an inner surface, a hanger configured to be received within the passage of the wellhead housing and couple to the inner surface of the housing, a tubular string configured to be received in the passage of the wellhead housing, wherein the tubular string includes a passage, a choke coupled to the tubular string and configured to control a fluid flow through the passage of the tubular string, and a wellhead connector configured to releasably couple to an end of the wellhead housing and including a first passage in fluid communication with passage of the tubular string when the wellhead connector is coupled to the wellhead housing.