A wellbore system includes a tubing hanger positioned within a wellhead and a Christmas tree (XT) coupled to the tubing hanger. The wellbore system also includes an annulus isolation device (AID). The AID includes a manual actuator configured to drive a wedge in a linear direction. The AID also includes a mating wedge arranged within an annulus flow path, the mating wedge configured to receive a force responsive to movement of the wedge. The AID further includes a stab coupled to the mating wedge, the stab configured to move in an axially downward direction responsive to movement of the mating wedge, the stab having a slotted portion moveable into alignment with an annulus passage to permit flow into the annulus flow path.

An autonomous BOP system is provided for stopping an uncontrolled flow of formation hydrocarbons comprising two or more sensors distributed along a length of a subsea blowout preventer to monitor a drill pipe inside a blowout preventer and measure critical parameters. A computer using predictive-software monitors a blowout preventer along with material critical parameters and calculates a blowout preventer configuration and sequence to arrest a well blowout. Blowout preventer components are fine-tuned and operational modes are added to aid an arrest of a well blowout under realistic conditions.

A high capacity universal connector for use in connecting tubular members and a method for sealing the tubular members is provided. First and second tubular members are provided which each have ends that are brought into face-to-face engagement by a connector. A metal sealing element seals against conical surfaces at the ends of the first and second tubular members and enables the entire surface of the end of one tubular member to be bought into engagement with the surface of the end of the other tubular member so as to improve the bending and compression capacity of the assembly comprising the tubular members and the metal sealing element. A metal sealing ring for use in this assembly is also provided, along with a gasket retention assembly.

A valve assembly (100) is disclosed, for controlling fluid communication along a well tubular (10). The valve assembly comprises: a hydraulically operated valve (40, 42) comprising a valve member (41, 43) which is movable between open and closed positions, and a hydraulic actuator (148) associated with the valve member for moving the valve member between these positions; a control system (146) for selectively controlling the flow of hydraulic fluid to and from the actuator, to operate the valve; a vent chamber (84) operatively connectable to the actuator, for selectively receiving hydraulic fluid exhausted from the actuator when the valve member is moved to its closed position; and a vent conduit (172) operatively connectable to the actuator, for selectively receiving hydraulic fluid exhausted from the actuator when the valve member is moved to its closed position, the vent conduit being exposed to fluid external to the valve assembly at the prevailing external pressure. The control system has a first valve closing state in which the vent chamber is isolated from the actuator and fluid exhausted from the actuator during movement of the valve member to its closed position is vented to an exterior of the valve assembly through the vent conduit. The control system has a second valve closing state in which fluid exhausted from the actuator during movement of the valve member to its closed position is vented into the vent chamber. The control system is configurable in a selected one of the first and second valve closing states according to an operating requirement of the valve. A control assembly for a valve, and a method of operating the valve assembly, are also disclosed.

A safety node for a hydrocarbon extraction facility control system, the node comprising: a hydraulic input; a hydraulic output; a directional control valve disposed between the hydraulic input and the hydraulic output; and a functional safety electronics module containing a logic solver in operable communication with the directional control valve; wherein the logic solver is configured to operate the directional control valve to permit hydraulic communication between the hydraulic input and the hydraulic output in response to the presence of a given condition and inhibit hydraulic communication between the hydraulic input and the hydraulic output in response to the absence of a given condition.

An assembly includes an inlet hub (112) coupled to a first flow passage (124) located within a flow control module, the first flow passage having a first flow bore, a flow meter (144) associated with the first flow bore and positioned for top-down fluid flow, a choke (109) disposed in a second flow passage (136) having a second flow bore, and an outlet hub (119) coupled to a distal end of the second flow passage. A system includes a flow control module assembly (902) having an inlet (912) and at least two outlets (914, 916), a main line (920) in fluid communication with the inlet, a first branch line (922) coupled to the main line and to a first outlet (916) of the at least two outlets, and a second branch line (924) coupled to the main line and to a second outlet (914) of the at least two outlets, and a tie-in connector (918) coupled to the inlet of the flow control module assembly.

An assembly includes an inlet hub (112) coupled to a first flow passage (124) located within a flow control module, the first flow passage having a first flow bore, a flow meter (144) associated with the first flow bore and positioned for top-down fluid flow, a choke (109) disposed in a second flow passage (136) having a second flow bore, and an outlet hub (119) coupled to a distal end of the second flow passage. A system includes a flow control module assembly (902) having an inlet (912) and at least two outlets (914, 916), a main line (920) in fluid communication with the inlet, a first branch line (922) coupled to the main line and to a first outlet (916) of the at least two outlets, and a second branch line (924) coupled to the main line and to a second outlet (914) of the at least two outlets, and a tie-in connector (918) coupled to the inlet of the flow control module assembly.

The method of providing blowout preventer ram actuator which will move a blowout preventer shear ram into the bore of the blowout preventer and retract the blowout preventer shear ram from the bore of the blowout preventer, comprising providing a first and second piston, pressuring the second cylinder extension area to move the blowout preventer shear ram into contact with the pipe to be sheared while venting the second cylinder, sensing that the blowout preventer shear ram has contacted the pipe to be sheared, pressuring the first and the second cylinder to shear the pipe and pressuring the first cylinder to retract the shear ram.

A system includes a first split riser, a second split riser, and a gasket. The first split riser includes a first half pipe having a first radial extension and a second radial extension. The first radial extension and the second radial extension have a mating surface. The second split riser includes a second half pipe having a third radial extension and a fourth radial extension. The third radial extension and the fourth radial extension have a corresponding mating surface. The gasket is installed on the mating surface of the first radial extension and the second radial extension. The gasket mates with the corresponding mating surface to form a connection between the first split riser and the second split riser.

The invention relates to a subsea wellhead support system (1) comprising: —a foundation assembly (2); —a conductor housing (31) for supporting a wellhead (4); —a connection arrangement (5) between the foundation assembly (2) and the conductor housing (3′); wherein the connection arrangement (5) is configured to releasably connect the conductor housing (3′) to the foundation assembly (2), such that: —during installation of the subsea wellhead support system (1), the conductor housing (1) can be fixed relative the foundation assembly (2), and—after installation of the subsea wellhead support system (1), the connection arrangement (5) can be released from the foundation assembly (2) allowing the conductor housing (3′) to move parallel along a longitudinal direction of a throughgoing opening of the conductor housing (31).