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: Systems and methods for proper orientation of the connections of a tubing hanger and a subsea assembly in a wellhead or tree are provided. The alignment is accomplished with the use of an orientation spool adaptor equipped with positional sensors and an orientation helix. Calibration of the positional sensors at the surface allows for orientation with simple vertical deployment. Positional sensors may provide real time data such as location, speed of installation and orientation back to the surface.

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 system includes a tubing hanger configured to be positioned in a wellhead assembly, the tubing hanger configured to support a tubing string, the tubing hanger including: a bore extending at least partially through the tubing hanger; and a valve disposed along the bore of the tubing hanger, wherein the valve is configured to control the flow of a fluid medium through the bore, and wherein the valve includes: an electrical actuator, wherein the electrical actuator is disposed at least partially within the tubing hanger, and wherein the electrical actuator is configured to selectively open or close the valve in response to one or more electrical signals.

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 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: Systems and methods for proper orientation of the connections of a tubing hanger and a subsea assembly in a wellhead or tree are provided. The alignment is accomplished with the use of an orientation spool adaptor equipped with positional sensors and an orientation helix. Calibration of the positional sensors at the surface allows for orientation with simple vertical deployment. Positional sensors may provide real time data such as location, speed of installation and orientation back to the surface.

Abstract: A subsea production system and method for installing the same are provided. The subsea production system includes a high pressure subsea wellhead, a tubing hanger landed proximate the wellhead, a production tree disposed above the wellhead downstream of the tubing hanger, a riser, a subsea flowline system coupled between the production tree and the riser, at least one barrier located downstream of the tubing hanger, and a secondary barrier valve disposed within the tubing hanger or in line with and upstream of the tubing hanger. The at least one barrier provides a pressure barrier that controls pressure of fluid flowing from components of the subsea production system located upstream of the barrier to components of the subsea production system located downstream of the barrier, and the secondary barrier valve is remotely actuable between a closed position and an open position.

Abstract: A drive shaft bearing support assembly is disclosed. The assembly may include a bearing support housing structured to be mountable to a portion of a vehicle. The bearing support housing may define a cavity structured for receiving a portion of a bearing therein. The assembly may also include a bearing support housing cap structured to be securable to the bearing support housing to secure the bearing in the cavity. The bearing support housing cap may be structured to contact the bearing only along two discrete regions of contact when the bearing support housing cap is secured to the bearing support housing to secure the bearing in the cavity.

Abstract: A drive shaft bearing support assembly is disclosed. The assembly may include a bearing support housing structured to be mountable to a portion of a vehicle. The bearing support housing may define a cavity structured for receiving a portion of a bearing therein. The assembly may also include a bearing support housing cap structured to be securable to the bearing support housing to secure the bearing in the cavity. The bearing support housing cap may be structured to contact the bearing only along two discrete regions of contact when the bearing support housing cap is secured to the bearing support housing to secure the bearing in the cavity.

Abstract: A subsea production system and method for installing the same are provided. The subsea production system includes a high pressure subsea wellhead, a tubing hanger landed proximate the wellhead, a production tree disposed above the wellhead downstream of the tubing hanger, a riser, a subsea flowline system coupled between the production tree and the riser, at least one barrier located downstream of the tubing hanger, and a secondary barrier valve disposed within the tubing hanger or in line with and upstream of the tubing hanger. The at least one barrier provides a pressure barrier that controls pressure of fluid flowing from components of the subsea production system located upstream of the barrier to components of the subsea production system located downstream of the barrier, and the secondary barrier valve is remotely actuable between a closed position and an open position.

Abstract: In accordance with the present disclosure, a full top-to-bottom subsea system and method used to drill, complete, produce, and perform interventions on HPHT subsea wells is provided. The disclosed systems and methods involve the use of a controlled multiple barrier system, such as a high integrity pipeline protection system (HIPPS), incorporated into the subsea system to divide the system into two sections. The sections on either side of the barrier may be rated for different pressures, temperatures, and/or flow rates. For example, the first section (upstream of the barrier) is rated for operating at pressures/temperatures/flow rates up to a first (higher) threshold. The second section (downstream of the barrier) is rated for operating at pressures/temperatures/flow rates up to a second (lower) threshold. The disclosed subsea production system methodology, which uses barriers to divide the system components between two pressure ratings, may allow for enhanced development of HPHT reservoirs.

Abstract: In accordance with the present disclosure, a full top-to-bottom subsea system and method used to drill, complete, produce, and perform interventions on HPHT subsea wells is provided. The disclosed systems and methods involve the use of a controlled multiple barrier system, such as a high integrity pipeline protection system (HIPPS), incorporated into the subsea system to divide the system into two sections. The sections on either side of the barrier may be rated for different pressures, temperatures, and/or flow rates. For example, the first section (upstream of the barrier) is rated for operating at pressures/temperatures/flow rates up to a first (higher) threshold. The second section (downstream of the barrier) is rated for operating at pressures/temperatures/flow rates up to a second (lower) threshold. The disclosed subsea production system methodology, which uses barriers to divide the system components between two pressure ratings, may allow for enhanced development of HPHT reservoirs.