The disclosure provides a downhole completion device for use in a wellbore and a subterranean production well. In one embodiment, the downhole completion device includes: (1) a hydraulic line controlled device, the hydraulic line controlled device having a control line port and one or more fluid leakage paths, and (2) a density barrier having first and second ends, wherein the first end is coupled to the control line port and the second end is configured to couple to a control line extending from a surface installation, the density barrier having an axial loop relative to the hydraulic line controlled device and positioned below the fluid leakage path, thereby preventing migration of leakage fluid from the one or more fluid leakage paths to the surface installation.

A modular manifold system includes a first manifold ring which comprises a first tubular body defined by an inner wall, an outer wall, a first end, and a second end. The inner wall and the outer wall extend between the first end and the second end. The first manifold ring also includes a first path formed between the inner wall and the outer wall and extending to at least one of the first end and the second end. At least one of the first end and second end comprises a coupling feature configured to couple the first manifold ring to a second manifold ring or well equipment. The first path is put in fluid communication or electrical communication with the second manifold ring or well equipment when the first manifold ring is coupled to the second manifold ring.

A technique which enables construction and operation of a subsea landing string system having a system manifold or manifolds unprotected by a dielectric fluid compensated enclosure. The manifolds contain directional control valves and corresponding solenoids which are able to operate while being exposed to environmental fluids such as seawater. The ability to operate manifolds in an unprotected environment enables the manifolds to be positioned in a variety of locations along the subsea landing string system or in cooperation with the subsea landing string system. The subsea landing string system also may be a modular system in which manifolds are added or removed according to the parameters of a given operation.

A valve seat for a valve is disclosed, the valve seat facilitating cutting of a body located within the seat. The valve seat includes a sealing surface for sealing with a valve member and an annular cutting component having a plurality of cutting teeth. The cutting teeth are circumferentially spaced and each defines an elongate crest. A valve is disclosed having a housing with a bore), a valve member and the valve seat. The valve seat is arranged within the housing in communication with the housing bore. The valve member is movable relative to the housing between an open position and a closed position.

A subsea test tree comprises a housing defining a flow path, a valve member mounted in the housing and an actuator coupled to the housing. A drive arrangement extends through a wall of the housing to operatively connect the actuator to the valve. The actuator is operable to operate the valve member to control fluid flow along the fluid pathway. Also disclosed are improvements to actuators.

A technique facilitates automatic shut-in of a well and disconnect of a corresponding landing string. The landing string is employed in a well application and comprises a landing string module which measures a parameter or a variety of parameters. Those parameters may be used to determine the occurrence of an event which initiates shut-in of the well and disconnect of the landing string. The subsea landing string system is constructed to enable autonomous shut-in and disconnect.

A valve apparatus comprises a housing defining a flowpath extending between a valve inlet and a valve outlet and an access port formed in a wall of the housing separately from the valve inlet and the valve outlet to provide access to the flowpath at a location which is intermediate the valve inlet and valve outlet. A valve mechanism is mounted within the flowpath, wherein the valve mechanism in insertable through the access port.

To be accompanied, when published, with FIG. 1.

A testable back pressure valve for controlling fluid flow through a bore of a component installed in a well bore is disclosed. The back pressure valve includes a valve body which is configured to be secured in the bore, a flow bore which extends through the valve body, at least a first body seal which is configured to seal the valve body to the bore, and a poppet which is movably positioned in the valve body. At least a first poppet seal is sealingly engaged between the poppet and the valve body when the poppet is in the closed position, and a test port extends through the valve body to below the first poppet seal when the poppet is in the closed position. Thus, with the back pressure valve installed in the flow bore and the poppet in the closed position, the first poppet seal can be pressure tested by communicating test pressure through the test port to below the first poppet seal.

A method of actuating a subsea tree comprising opening a valve assembly by transferring a first volume of fluid into a first chamber and closing the valve assembly from the open position to a shear position via a gas charged valve actuator in response to the transfer of fluid out of the first chamber. Shearing a workstring positioned within an axial bore of the valve assembly with the valve via the gas charged valve actuator. Closing the valve from the shear position to a closed position with one or more gas charged push rods to isolate the wellbore above from the wellbore below the closed valve. The shearing force generated from the gas charged valve actuator is greater than the closing force of the one or more push rods.

Methods for deploying a coiled tubing string into a wellbore include providing a coiled tubing having a distal end and an opposing end connected with a reel, providing a tool including a tool body, a valve operable under wellbore pressure disposed within the tool body, and a first fluid passageway and a second fluid passageway defined within the tool body. Fluid communication is established through the distal end of the coiled tubing and the first fluid passageway and the second fluid passageway, and the coiled tubing and tool are deployed into the wellbore.