-a subsea pump (30) arranged in fluid connection with the well interior (38, 39) providing a closed system suitable for pressure and flow regulation and establishing a temporary fluid flow between the subsea pump and the well interior, -a fluid source (31) supplying fluid to the subsea pump, wherein the subsea pump has a mode of operation for regulation of the flow and/or pressure between the pump and the well interior to operate equipment arranged in the well, -a safety control system for controlling shut down of a valve arrangement in a subsea position, which safety control system is also arranged in a subsea position and comprises a control unit (60) and an actuation unit (70) for local control and operation of the valve arrangement, - the valve arrangement is operated by the control unit into a valve configuration providing a barrier system between a reservoir in fluid communication with the well interior and the surroundings, -a plurality of sensors (100, 51, 52) arranged for measuring fluid parameters transmitted as signals to the control unit, which also receives other signals from subsea and or topside locations, where the control unit is configured such that when at least one transmitted signal deviates from allowable value the control unit activates the actuation unit for the closing of the valve arrangement. The invention also concerns a method.

-a subsea pump (30) arranged in fluid connection with the well interior (38, 39) providing a closed system suitable for pressure and flow regulation and establishing a temporary fluid flow between the subsea pump and the well interior, -a fluid source (31) supplying fluid to the subsea pump, wherein the subsea pump has a mode of operation for regulation of the flow and/or pressure between the pump and the well interior to operate equipment arranged in the well, -a safety control system for controlling shut down of a valve arrangement in a subsea position, which safety control system is also arranged in a subsea position and comprises a control unit (60) and an actuation unit (70) for local control and operation of the valve arrangement, - the valve arrangement is operated by the control unit into a valve configuration providing a barrier system between a reservoir in fluid communication with the well interior and the surroundings, -a plurality of sensors (100, 51, 52) arranged for measuring fluid parameters transmitted as signals to the control unit, which also receives other signals from subsea and or topside locations, where the control unit is configured such that when at least one transmitted signal deviates from allowable value the control unit activates the actuation unit for the closing of the valve arrangement. The invention also concerns a method.

A method of manufacturing a configurable pre-machined forging for use with a multiple bore tubing hanger or a mono bore tubing hanger includes providing a configurable common master valve block with a main bore along a main central axis. After providing the configurable common master valve block, a target subsea assembly is identified that has a mono bore subsea completion with a production bore along a central axis of a tubing hanger, or a multiple bore subsea completion with the production bore offset from the central axis of the tubing hanger. If the target subsea assembly has the mono bore subsea completion, the machining of a lower interface of the common master valve block is centered around the main central axis. If the target subsea assembly has the multiple bore subsea completion, the machining has an eccentric interface axis that is parallel to, and offset from, the main central axis.

A method of manufacturing a configurable pre-machined forging for use with a multiple bore tubing hanger or a mono bore tubing hanger includes providing a configurable common master valve block with a main bore along a main central axis. After providing the configurable common master valve block, a target subsea assembly is identified that has a mono bore subsea completion with a production bore along a central axis of a tubing hanger, or a multiple bore subsea completion with the production bore offset from the central axis of the tubing hanger. If the target subsea assembly has the mono bore subsea completion, the machining of a lower interface of the common master valve block is centered around the main central axis. If the target subsea assembly has the multiple bore subsea completion, the machining has an eccentric interface axis that is parallel to, and offset from, the main central axis.

The annular space surrounding a flow tube in a subsurface safety valve is sealingly isolated at opposed ends of the flow tube and pressure compensated to the tubing pressure. The subsurface safety valve is inserted and aligned in an outer housing so that hydraulic operating connections are sealingly aligned with opposite hand split ring seals that are properly compressed when the safety valve is secured in its surrounding housing. The assembly is then able to meet high pressure, heavy debris, and marine environment service requirements for subsea conditions with minimal reconfiguration for what would otherwise serve as a borehole subsurface safety valve.

A subsea test tree assembly is provided which includes at least one subsea test tree or SSTT, the SSTT including a valve having at least one of a cutting function and a sealing function, the valve being movable between an open position and a closed position via hydraulic fluid supplied to the valve through control lines; and a control system including a source of hydraulic fluid, the control system being arranged to supply hydraulic fluid from the source of hydraulic fluid to the valve of the at least one SSTT on detecting that the control lines have been sheared, to automatically move the valve to the closed position. A method of controlling a well using an SSTT assembly is also provided.

A subsea test tree assembly is provided which includes at least one subsea test tree or SSTT, the SSTT including a valve having at least one of a cutting function and a sealing function, the valve being movable between an open position and a closed position via hydraulic fluid supplied to the valve through control lines; and a control system including a source of hydraulic fluid, the control system being arranged to supply hydraulic fluid from the source of hydraulic fluid to the valve of the at least one SSTT on detecting that the control lines have been sheared, to automatically move the valve to the closed position. A method of controlling a well using an SSTT assembly is also provided.

The present invention relates to hydrocarbon well fluid manifold module (1) with a manifold module housing (9) having a transversal bore terminating in a longitudinal bore (3) in fluid connection with the transversal bore (6). One or more cut off valves are located (7) in the transversal bore (6). The longitudinal bore (3) extend through the module housing (9) and form a first flow port (11) and a second flow port (12) aligned with the first flow port (11). Plane, connecting surfaces surround the two flow ports (11,12). The two flow ports and connecting surfaces are identical. The first connecting surface (13) and the second connecting surface (14) are adapted to be connected to at least one further similar manifold module (20). The invention also concerns a manifold for a hydrocarbon well assembled of such modules.

A dynamically positioned vessel (DPV) is located above an injection well, inject water or other fluids temporarily or for a short period of time, adjust the injection parameters, and either continue operating for the life of the system or as long as required to add permanent facilities on another platform. The DPV is connected to the potential injection well via a hybrid riser system. The hybrid riser system includes a rigid portion and a flexible portion. Injection using the DPV and the hybrid rise system can be more economical than injection using a conventional mobile offshore drilling unit (MODU) and a rigid riser.

A dynamically positioned vessel (DPV) is located above an injection well, inject water or other fluids temporarily or for a short period of time, adjust the injection parameters, and either continue operating for the life of the system or as long as required to add permanent facilities on another platform. The DPV is connected to the potential injection well via a hybrid riser system. The hybrid riser system includes a rigid portion and a flexible portion. Injection using the DPV and the hybrid rise system can be more economical than injection using a conventional mobile offshore drilling unit (MODU) and a rigid riser.