Cooper Cameron Corporation

Hydril Company

Cameron International Corporation

Danny K Wolff

James D Mott

Edwin C Turner

Gerald S Baker

William M Taylor

John C Vicic

Brian Hart

Kenneth W Colvin

David Garnham

Mark L Carter

A wellhead assembly for use on a well with a blowout preventer stack having a bore therethrough that utilizes an intervention spool sealingly secured between a horizontal tree and the blowout preventer stack to allow the use of a removable valve package positioned in the intervention spool with valve actuators mounted on the exterior of the intervention spool is disclosed.

Intervention spool for subsea use

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

The method and apparatus includes lowering a blanking plug assembly into the bore of an oilfield tubular member and inserting a sealing assembly on the blanking plug assembly into the seal bore of the tubular member without sealingly engaging the seal bore. A support shoulder on the blanking plug assembly lands on the landing shoulder of the oilfield tubular member. Wireline jars jar down on the lock sleeve of the blanking plug assembly to shift dog members radially outward into latching grooves in the oilfield tubular member. The lock sleeve then locks the dog members into the latching grooves. The wireline jars then jar up on a plug of the blanking plug assembly to move the plug upwardly to an upper position within the blanking plug assembly. The sealing assembly is prevented from moving upward and a tapered surface on the plug is driven through the sealing assembly thereby radially energizing the sealing assembly into sealing engagement with the outer tubular member. As the plug moves upwardly, latch members disposed on the blanking plug assembly are received by grooves in the plug to maintain the plug in its upper position. The method provides definitive indications as to whether the dog members are locked into place, whether the sealing assembly is in metal-to-metal engagement with the outer tubular member, and whether the plug is latched in its upper position.

Blanking plug assembly

A fluid coupling, e.g., a subsea coupling, includes male and female parts which can be coupled together. The female part includes four passages normally closed by a slidable gate. The male part includes four passages normally closed by a closure slide. When the male and female parts are coupled together, the gate is pushed aside by the gate part and becomes temporarily joined thereto, and the closure slide is pushed aside by the female part and is temporarily joined thereto. When the male and female parts are uncoupled, the gate and closure slide are moved back to their passage-closing positions. A metal sealing member for the passages includes annular thick and thin lips. The thin lip provides flexibility, and the thick lip engages a relatively movable part.

Multi-passage fluid coupling and metal seal therefor

An improved remotely operable safety valve which is adapted for use between the swivel and the kelly is disclosed. An annular hydraulic piston moves the valve to the open and closed position whether or not the drill string is rotating, and in the event of hydraulic failure, the valve may be operated manually. Centering spring means are provided to reduce wear on the operable elements when the valve is in the open position.

Remotely operable safety valve

Two embodiments of a surface controller system apparatus and their method for use with a surface controlled subsurface safety valve are disclosed. Both surface controller systems are responsive to an emergency shutdown signal for enabling closing of the subsurface safety valve when the well surface safety systems are shut-in. Once the subsurface Safety Valve has been shut-in up the system, the safety control system must be manually reset before the subsurface valve can be reopened. Both safety control system provides an enclosed reservoir or accumulator for receiving the hydraulic control fluid when the subsurface valve closes and for containing well blow-outs through either one or both control fluid conduits operably connecting the controller system with the subsurface valve. The enclosed systems are also arranged that any internal leakage of the surface control system will operate to shut-in the well with the subsurface valve. Undesired pressure buildup, effecting possible operation of the subsurface valve in either of the normal or vent control lines also automatically operates to shut-in the subsurface safety valve.

Growing community of inventors

Houston, TX, United States of America

Danny K Wolff