Onesubsea IP UK Limited

Cooper Cameron Corporation

Cooper Industries, Inc.

Other

Bp Exploration Operating Company Limited

Brian Hart

David Garnham

Cameron J Berry

Gerald S Baker

Danny K Wolff

Dennis Harwood

Craig Duell

A riser intervention system for use with a subsea test tree includes a lower riser package spool, an intermediate spool, and a riser stress joint. The lower riser package spool may include a bore and a shoulder projecting into the bore such that the subsea test tree is landable on the shoulder within the lower riser package spool. The intermediate spool is connectable to the lower riser package spool to secure the subsea test tree within the bore of the lower riser package spool such that the lower riser package spool is in fluid communication with the intermediate spool. The riser stress joint is releasably connectable to the intermediate spool using such that the intermediate spool is in fluid communication with the riser stress joint.

Subsea test tree intervention package

Sealing mechanisms are provided. In one embodiment, a system includes a connector configured to couple one or more flow-control valves to equipment installed at a well and an isolation sleeve configured to be retained by the connector. The isolation sleeve may include a seal and a hydraulically actuated piston disposed adjacent one another about a body of the isolation sleeve such that actuation of the piston engages the seal. The isolation sleeve may also include a mechanically driven actuator ring, where the actuator ring energizes a seal against the bore of a tubing hanger. Additional systems, devices, and methods are also disclosed.

Sealing mechanism for subsea capping system

A sealing mechanism is provided. In one embodiment, a system includes a connector configured to couple one or more flow-control valves to equipment installed at a well and an isolation sleeve configured to be retained by the connector. The isolation sleeve may include a seal and a hydraulically actuated piston disposed adjacent one another about a body of the isolation sleeve such that actuation of the piston engages the seal. Additional systems, devices, and methods are also disclosed.

A subsea production system for controlling fluid flow from a well. The system includes a subsea production tree and a drilling riser engageable with the well. The tree includes electrical and hydraulic lines to communicate with equipment in the tree and downhole in the well. The system also includes a tieback tool that can be installed in the tree through the drilling riser to establish communication with the tree electrical and hydraulic lines and permit access into the well bore. The system also includes an umbilical connectable with the tieback tool and extendable inside the drilling riser to the surface. The umbilical can be used to communicate the tieback tool. The umbilical can also be used to communicate with the tree and downhole equipment through the tieback tool connection with the tree.

Integrated installation workover control system

A high torque rotating actuator is disclosed. The high torque rotating actuator has a variable helix angle that allows the actuator to generate greater torque near the end of its travel when it is needed to close a valve or operate a choke. The high torque rotating actuator is designed for use with valves and chokes. In a second embodiment, a high torque rotating actuator is configured to give a shorter overall assembly. As in the preferred embodiment, a variable helix angle is used to generate greater torque near the end of its travel when it is needed to close a valve or operate a choke.

High torque rotating actuator

A subsea wellhead assembly is disclosed with an extension spool secured thereto and an in line tree assembly locked within the extension spool. Ball valves are disposed within the vertical bores of the in line tree assembly. Valve actuators are disposed radially on the extension spool with a cylindrical sleeve mounted coaxially around the one end of the actuator and rotatable relatively to the actuator about the common axis of the actuator and the sleeve, so that, when the actuator engages with the corresponding ball valve, the sleeve bridges the gap between the extension spool and the in line tree assembly to lock the in line tree assembly to the extension spool.

Subsea well head assembly

A hanger assembly comprising a tubular housing having an internal cylindrical bore provided with an annular recess containing a fixed, annular, downwardly tapering ramp, and, supported on the ramp, a split, radially contractible, wedge locking ring which normally adopts a relaxed position not projecting into the bore; and a tubular hanger having an external surface which is a clearance sliding fit in the bore and which is provided with resilient energising mechanism, which are recessed in the external surface and held there by engagement with the bore during running in of the hanger until the energising mechanism come into alignment with the annular recess, whereupon the energising mechanism expands radially outwards to overlie the locking ring, final running in of the hanger forcing the locking ring down the ramp and hence causing the ring to contract radially and to grip the external surface of the hanger.

Hanger assembly

A wellhead assembly in which an in-line tree (10) is landed within a wellhead housing (3). The in-line tree has a vertical production through bore (11), two hydraulically or electrically controllably in-line valves (13A, 13B) in the vertical production bore, and a lateral bore (16) leading from the vertical production through bore. A horizontal tree (20) having a vertical through bore (23) is landed on the wellhead housing (3) so that the in-line tree (20) is within the vertical bore. The horizontal tree has a lateral bore (24) which is aligned with the lateral bore (16) of the in-line tree. The in-line tree (10) can be run in and retrieved through the horizonal tree (20). Alternatively the horizontal tree (20) can be removed from the wellhead housing (3) without a BOP if the in-line valves (13A, 13B) are closed.

Wellhead assembly

A connector for connecting two tubular members (1,2) having annular flanges (3,4) at their ends. The connector comprising an actuating ring (13) movable in the axial direction of the tubular members (1,2), a plurality of upper dogs (15) for engaging the flange (3) of the upper tubular member (1) and a corresponding plurality of lower dogs (17) for engaging the flange (4) of the lower tubular member (2). Each pair of upper (15) and lower (17) dogs are connected by a stud (24) and are axially separable providing a sealed cavity (22) between the dogs which is supplied, in use, with hydraulic fluid. In use, the supply of hydraulic fluid to the cavity (22) forces the upper (15) and lower (17) dogs apart to tension the stud, so that, when the dogs are moved adjacent to the upper and lower flanges (3,4) and the pressure in the cavities (22) is released, the tension in the stud will be released allowing the upper (15) and lower (17) dogs to slide back together and clamp the upper (3) and lower (4) flanges together.

Wellhead connector

A sealing assembly for sealing between two relatively rotatable cylindrical surfaces. The assembly comprises two seal parts (46, 48) disposed in a groove (40) in one of the surfaces so that one of said parts is disposed radially outwardly of the other. One (46) of the parts is movable axially relative to the other (48) to effect setting of the sealing assembly and the groove (40) and parts (46, 48) are so dimensioned that they become compressed between the surfaces during setting of the assembly. Adjacent surfaces of the seal parts (46, 48) may have inter-engaging profiles (55) which permit relative movement for setting the assembly, but resist movement in the opposite direction.

Sealing assembly

An adjustable connection apparatus for joining tubular members including a first tubular member with a central bore, a counterbore on one end thereof, a flange on the other end thereof and external fine pitch grooves and ridges, a second tubular member with a central bore, a flange on one end thereof, a first reduced external diameter portion on the opposite end for insertion into said counterbore of said first tubular member, a second reduced diameter portion on the end of said first reduced diameter portion with external threads on the end of said second reduced diameter portion and external fin pitch grooves and ridges, clamping elements having internal fine pitch grooves and ridges for gripping engagement with the external grooves and ridges of said tubular members and means for securing the clamping elements together in gripping engagement with the tubular members to secure them into a joint having a preselected length and sealing means between the tubular members.

Growing community of inventors

Wakefield, United Kingdom

Brian Hart