Schlumberger Technology Corporation

Onesubsea IP UK Limited

John R Meijer

Jason Keith Jonas

David Verzwyvelt

Raghuram Kamath

Robert Scott Neves

Mangesh Edke

Dinesh R Patel

Gary L Rytlewski

Adam Tusing

Mahesh Shenoy

Jiju Ninan

An improved swivel with increased sealing capability at fluid pressures up to 20 ksi and at fluid temperatures as high as 250&#xb0; F. and as low as 35&#xb0; F. The swivel may be relatively compact, being less than 8 feet in overall length and can operate unpressurized with axial loads of at high as 1,400,000 lbs. The swivel may comprise a swivel mandrel rotationally coupled with a swivel housing. Rotational bearings units can be securely held using cartridge carriers. A pressure seal may be formed between the swivel mandrel and swivel housing via a redundant seal stack.

Swivel for subsea string

A ball valve assembly includes a ball having a fluid pathway and a leading edge portion. The ball is configured to rotate between an open position and a closed position, the fluid pathway is configured to align with a fluid passage while the ball is in the open position, and the fluid pathway is configured to be offset from the fluid passage while the ball is in the closed position. Furthermore, the leading edge portion includes a first leading edge configured to cut a line extending through the fluid pathway as the ball rotates from the open position to the closed position, the leading edge portion includes a second leading edge configured to engage a seal of the ball valve assembly as the ball rotates from the open position to the closed position, and the first leading edge is positioned radially inward from the second leading edge.

Ball valve assembly

A valve assembly includes a ball configured to block fluid flow through the valve assembly while the ball is in a closed position and to enable fluid flow through the valve assembly while the ball is in an open position. The valve assembly also includes an actuator assembly configured to drive the ball to transition between the open position and the closed position. In addition, the valve assembly includes multiple compression springs disposed on one side of the ball. Each compression spring of the multiple compression springs is configured to directly urge the ball toward the closed position.

Failsafe close valve assembly

A connection system includes a turnbuckle having a first set of threads and a second set of threads disposed on an inner surface of the turnbuckle. The turnbuckle is configured to couple two threaded components to one another via rotation of the turnbuckle in a first direction. In addition, the connection system includes a compression washer configured to compress as the turnbuckle rotates in the first direction. The compression washer is configured to apply a longitudinal force to the turnbuckle while the compression washer is compressed to increase resistance to rotation of the turnbuckle in a second direction, opposite the first direction.

Connection system for a well string

A wellbore packer having a setting mechanism adapted to apply an axial force along a force path; a seal member connected with the setting mechanism along the force path, the seal member set in response to the application of the axial force; a slip connected with the setting mechanism downstream of the seal member along the force path, the slip set in response to the application of the axial force; and an assembly adapted to transfer the axial force around the intervening seal member to the slip.

Wellbore packer

A technique is provided in which a soft landing system is used for connecting upper and lower assemblies in a wellbore. The soft landing system cushions the engagement of an upper well assembly with a lower well assembly and facilitates the controlled engagement of control line connectors. The controlled engagement limits or avoids damage to the control line connectors in well completion operations performed in two or more stages.

Downhole connection system

A technique is provided to facilitate connection of well equipment assemblies at a downhole location. A first assembly comprises a control line having a connector designed for coupling with a corresponding connector of a next adjacent assembly. Additionally, a mechanism is provided to restrain movement of the next adjacent assembly prior to full engagement with the first assembly to enable performance of a desired preparation procedure.

A technique is provided in which a contraction joint is used to facilitate connection of well equipment assemblies at a downhole location. The contraction joint accommodates changes in system length during engagement and use or the well equipment assemblies in a wellbore. Additionally, the contraction joint provides a positive indication of joint position and enables resetting of the joint following initial contraction.

A latching assembly includes a first mating portion and a second mating portion disposed adjacent and rotationally restrained relative to the first mating portion. A first cam member having a first cam profile is mounted on the first mating portion. A second cam member having a second cam profile is mounted on the second mating portion. The second cam profile is adapted to inter-fit with the first cam profile. Torque induced by the cam members when the cam profiles are engaging rotates the first cam member until the first cam profile is inter-fitted with the second cam profile.

Growing community of inventors

Sugar Land, TX, United States of America

John R Meijer