A subsea well intervention method implemented on a well (200) from a floating vessel (100), said floating vessel not comprising a derrick, the method comprising a step of connecting a power line (207) directly between a remotely operated vehicle (206) and the blowout preventer module (202) for powering the blowout preventer module, the remotely operated vehicle (206) being connected to a control unit (107) located on the floating vessel via a remotely operated vehicle umbilical (106).

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 control unit includes a hydraulic fluid system, a lubricant system, at least one sensor cable, an electronics module in communication with the at least one sensor cable, the hydraulic fluid system, and the lubricant system. A housing of the control unit contains the hydraulic fluid system, the lubricant system, the sensor cable(s), and the electronics module.

Electric valve actuator, comprising: a stem (41, 43) for moving a valve member between open and closed positions; a drive assembly for moving the stem comprising an electric motor (31); a biasing assembly (5) adapted to act on the stem to urge it toward a failsafe position; and a fail-safe shutdown system to allow the biasing assembly to urge the stem toward the failsafe position, comprising a first latching unit (7) mounted movable in translation in the housing and a second latching unit (8) mounted on the housing for latching engagement with the first unit, whereby the stem can be moved free from the action of the biasing assembly in the latched state of the first and second latching units; and the drive assembly and the stem are mounted integral in translation with the first unit (7), which is mounted integral in translation with the biasing 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 method for determining a predictive life of a pressure containing component includes determining, from sensor data, one or more cycles. The method also includes generating one or more additional cycles. The method further includes determining a component feature is below a threshold. The method further includes generating one or more supplementary cycles. The method also includes determining, from the one or more cycles, the one or more additional cycles, and the one or more supplementary cycles, the component feature. The method includes determining the component feature exceeds the threshold. The method further includes determining, based at least in part on the one or more supplementary cycles, a predictive life for the pressure containing component.

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.

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 temperature sensor system for a nitrogen tank with a subsea blowout preventer that monitors temperature of the nitrogen in the tank. It is also contemplated to remove rupture discs and utilize a relief valve, which may be assembled with the temperature sensor system.