Halliburton Energy Services, Inc.

Christopher Robert Delzell

William Mark Richards

Bryon David Mullen

William David Henderson

Eddie Eddieberto Perez

Phillip Terry Thomas

Mark Douglas Macek

The disclosed embodiments include shiftable covers, completion systems, and methods to shift a downhole cover in two directions. A shiftable cover includes a hollow interior configured to receive a diverter flowing in a first direction. The shiftable cover also includes a diverter seat disposed in the hollow interior and configured to retain the diverter. The shiftable cover also includes a plurality of segments configured to collapse in response to shifting of the shiftable cover from a first position to a second position to retain the diverter, and un-collapse in response to shifting of the shiftable cover from the second position towards the first position.

Shiftable covers, completion systems, and methods to shift a downhole cover in two directions

Downhole setting systems and methods for setting downhole tools in subterranean formations. An example downhole setting system comprises a downhole setting assembly and a downhole tool configured to be set by the downhole setting assembly. The downhole setting assembly comprises a setting piston, and a mating element that physically constrains the setting piston from translating; the mating element configured to release and permit the setting piston to translate.

Anti-preset mechanism for setting piston in downhole tools

A collet includes a cylindrical body, and a plurality of longitudinally-extending orifices defined through the body and thereby providing one or more axially-extending collet fingers. A collet lug is removably coupled to each axially-extending collet finger.

Adjustable and redressable collet

A system includes a downhole tool assembly extendable within a wellbore. A running tool axially interposes the downhole tool assembly and the conveyance and includes an elongate body providing an interior and one or more radial protrusions. A connection sub is disposed about the body and provides a releasable connection engageable with the downhole tool assembly. A torque sleeve is disposed about the body and at least a portion of the connection sub. A connection sub piston interposes the body and the connection sub and is axially movable between a supported position, where the connection sub piston radially supports the connection sub, and an unsupported position, where at least a portion of the connection sub is radially unsupported by the connection sub piston. Increasing pressure within an annulus between the running tool and the wellbore moves the connection sub piston from the supported position to the unsupported position.

Annulus pressure release running tool

A method of actuating a downhole component comprises positioning a magnetic positioning tool adjacent an actuable component within a wellbore, where the magnetic positioning tool comprises a plurality of magnets arranged in a first position, transitioning the plurality of magnets from the first position to a second position, detecting the plurality of magnets using a sensor associated with the actuable component, generating a signal indicative of the plurality of magnets being in the second position, and actuating the actuable component within the wellbore in response to the signal.

Selective magnetic positioning tool

An actuation device comprises a housing, and a plurality of permanent magnets disposed about the housing. The plurality of permanent magnets is configured to selectively transition between a first position and a second position. The plurality of permanent magnets is configured to provide a stronger magnetic field strength outside the housing than inside the housing in the first position, and wherein the plurality of permanent magnets is configured to provide a stronger magnetic field strength inside the housing than outside the housing in the second.

A multiple control line travel joint is disclosed having at least one non-coiled, fluid control line and at least one internal control line, such as a hydraulic, electrical, or fiber optic control line. The fluid control line can include an upper control line that enters the travel joint at a top port and a lower control line that exits out a bottom port of the travel joint. The top port and bottom port can be fluidly coupled through a sealed chamber in the travel joint. The second control line can be coiled within the sealed chamber. As the travel joint expands and contracts, the sealed chamber expands and contracts while remaining sealed, maintaining sealed fluid coupling between the top port and the bottom port.

Multiple control line travel joint with injection line capability

A well packer includes an expandable member carried on a mandrel, the mandrel including a groove formed on at least a portion of an outer radial surface of the mandrel; a back-up assembly carried on the mandrel adjacent the expandable member; and a fold back assembly carried on the mandrel adjacent the back-up assembly, the fold back assembly including a snap ring carried on the mandrel and adapted to move into the groove and adjust the expandable member into an expanded position in substantially sealing contact with a tubular.

Assisting retrieval of a downhole tool

A well tool includes: a well packer; a hydraulic sub-assembly coupled to the well packer; an anti-preset assembly coupled to the hydraulic sub-assembly; a slip assembly coupled to the anti-preset assembly; and a fold-back assembly coupled between the well packer and the hydraulic sub-assembly. The well packer includes an expandable member that rides on a mandrel extending at least a portion of the well tool. The fold-back assembly includes a bias member carried on the mandrel and adapted to engage a profile formed on the mandrel based on a setting stroke that adjusts the expandable member into an expanded position in substantially sealing contact with a tubular.

Disclosed are circulating sleeves that can be opened and closed and permanently closed. A disclosed completion system includes a completion string having a circulating sleeve movably arranged therein, the circulating sleeve having a locking profile defined on an outer radial surface thereof and a shifting profile defined on an inner radial surface thereof, a service tool configured to be arranged at least partially within the completion string and including a shifting tool having one or more shifting keys configured to mate with the shifting profile, wherein, when the shifting keys locate and mate with the shifting profile, an axial load applied on the service tool axially moves the circulating sleeve, and a release shoulder assembly arranged within the completion string and comprising a release shoulder that defines a channel configured to receive a locking mechanism occluded within the channel until the release shoulder is moved axially.

Growing community of inventors

Plano, TX, United States of America

Christopher Robert Delzell