Abstract: A reduced stroke gate valve is provided. The reduced stroke gate valve provides a predetermined or desired flow area for a given bore size through the gate valve while reducing a total length through which the gate valve strokes between an open position and a closed position. The reduced stroke gate valve includes one or more openings that span a non-circular or non-round area within the gate. The non-circular or non-round shape or distribution of opening(s) in the gate may provide a flow area equivalent to a predetermined flow area for a single circular hole that would otherwise be used for the gate valve application, but with a shape or distribution of opening(s) that provides a reduced stroke length to move the gate valve from the open position to the closed position.

Abstract: A subsea wellhead assembly having an arrangement of primary well barriers provided in equipment that is located within the well and/or the wellhead housing is provided. The subsea wellhead assembly may include a tubing hanger positioned in or below a wellhead housing coupled to a subsea well, a tree cap fluidly coupled to the tubing hanger and disposed atop the wellhead housing, and a pair of master production valves configured to be selectively actuated from an open position to a closed position to shut in the subsea well, each of the pair of master production valves located within or below the wellhead housing.

Abstract: A hanger assembly includes: a main body; a lock ring coupled to the main body and configured to expand radially outward into a profile on an inner diameter of the wellhead; and an actuator, wherein the actuator is capable of transferring an axial force from the actuator into outward radial expansion of the lock ring toward the profile on the inner diameter of the wellhead. An interface between the actuator and the lock ring is shaped such that: axially downward movement of the actuator from a starting position to an intermediate position actuates the lock ring into the profile; and axially downward movement of the actuator from the intermediate position to a pre-load position applies a pre-load to the hanger assembly.

Abstract: A subsea wellhead assembly having an arrangement of primary well barriers provided in equipment that is located within the well and/or the wellhead housing is provided. The subsea wellhead assembly may include a tubing hanger positioned in or below a wellhead housing coupled to a subsea well, a tree cap fluidly coupled to the tubing hanger and disposed atop the wellhead housing, and a pair of master production valves configured to be selectively actuated from an open position to a closed position to shut in the subsea well, each of the pair of master production valves located within or below the wellhead housing.

Abstract: A tubing: hanger assembly with a shiftable annulus seal is provided. The shiftable annulus seal allows for selectively sealing the tubing hanger within a easing hanger, a wellhead, or a tubing head. The tubing hanger assembly also includes a secondary annulus flow path formed through the body of the tubing hanger. The shiftable annulus seal selectively opens/closes a relatively large flow path to the tubing string annulus for circulation of fluid through the tubing string and setting a-packer. The secondary annulus flow path facilitates monitoring and bleeding of pressure front the annulus after the shiftable annulus seal is closed.

Abstract: A subsea wellhead assembly having an arrangement of primary well barriers provided in equipment that is located within the well and/or the wellhead housing is provided. The subsea wellhead assembly may include a tubing hanger positioned in or below a wellhead housing coupled to a subsea well, a tree cap fluidly coupled to the tubing hanger and disposed atop the wellhead housing, and a pair of master production valves configured to be selectively actuated from an open position to a closed position to shut in the subsea well, each of the pair of master production valves located within or below the wellhead housing.

Abstract: A subsea wellhead assembly having an arrangement of primary well barriers provided in equipment that is located within the well and/or the wellhead housing is provided. All of the well barriers may be located within the tubing hanger and/or the production tubing string extending into the wellbore. The subsea wellhead assembly also includes a flowline connection body placed atop the wellhead housing and fluidly coupled to the tubing hanger. None of the primary barriers for the well are located in the flowline connection body.

Abstract: A subsea wellhead assembly having an arrangement of primary well barriers provided in equipment that is located within the well and/or the wellhead housing is provided. The subsea wellhead assembly may include a tubing hanger positioned in or below a wellhead housing coupled to a subsea well, a tree cap fluidly coupled to the tubing hanger and disposed atop the wellhead housing, and a pair of master production valves configured to be selectively actuated from an open position to a closed position to shut in the subsea well, each of the pair of master production valves located within or below the wellhead housing.

Abstract: A space-out mechanism that may be used in a tubing hanger system to install a tubing hanger and rigidize the tubing hanger and a casing hanger within a wellhead housing in a single trip is provided. The space-out mechanism may include two pieces that are configured to rotate against each other such that the axial length of the space-out mechanism can be adjusted to remove any axial gaps created in the installation of the tubing hanger or rigidizing of the tubing hanger and casing hanger within the wellhead housing. The two pieces of the space-out mechanism may include a ramp ring and a piston. The ramp ring and piston may each have ramp surfaces that rotate and bear against each other until the system is rigidized.

Abstract: A subsea wellhead assembly having an arrangement of primary well barriers provided in equipment that is located within the well and/or the wellhead housing is provided. All of the well barriers may be located within the tubing hanger and/or the production tubing string extending into the wellbore. The subsea wellhead assembly also includes a flowline connection body placed atop the wellhead housing and fluidly coupled to the tubing hanger. None of the primary barriers for the well are located in the flowline connection body.

Abstract: A tubing: hanger assembly with a shiftable annulus seal is provided. The shiftable annulus seal allows for selectively sealing the tubing hanger within a easing hanger, a wellhead, or a tubing head. The tubing hanger assembly also includes a secondary annulus flow path formed through the body of the tubing hanger. The shiftable annulus seal selectively opens/closes a relatively large flow path to the tubing string annulus for circulation of fluid through the tubing string and setting a-packer. The secondary annulus flow path facilitates monitoring and bleeding of pressure front the annulus after the shiftable annulus seal is closed.

Abstract: A space-out mechanism that may be used in a tubing hanger system to install a tubing hanger and rigidize the tubing hanger and a casing hanger within a wellhead housing in a single trip is provided. The space-out mechanism may include two pieces that are configured to rotate against each other such that the axial length of the space-out mechanism can be adjusted to remove any axial gaps created in the installation of the tubing hanger or rigidizing of the tubing hanger and casing hanger within the wellhead housing. The two pieces of the space-out mechanism may include a ramp ring and a piston. The ramp ring and piston may each have ramp surfaces that rotate and bear against each other until the system is rigidized.

Abstract: A reduced stroke gate valve is provided. The reduced stroke gate valve provides a predetermined or desired flow area for a given bore size through the gate valve while reducing a total length through which the gate valve strokes between an open position and a closed position. The reduced stroke gate valve includes one or more openings that span a non-circular or non-round area within the gate. The non-circular or non-round shape or distribution of opening(s) in the gate may provide a flow area equivalent to a predetermined flow area for a single circular hole that would otherwise be used for the gate valve application, but with a shape or distribution of opening(s) that provides a reduced stroke length to move the gate valve from the open position to the closed position.