Ctc International Inc.

Halliburton Energy Services, Inc.

Baker Hughes Corporation

Weatherford/lamb, Inc.

Tam International, Inc.

Other

Dixie Iron Works, Ltd

Manifold Systems, Inc.

Robert T Brooks

Edward T Wood

Dan Parnell Saurer

David Joe Steele

Jody Ray McGlothen

David H Surgnier

Guy LaMont McClung, Iii

Daniel Jon Themig

John R Whitsitt

Paul James Wilson

Clayton Plucheck

Monty E Harris

Thad Joseph Scott

George O Suman, Jr

Mark Lewis Wyatt

Frank Victor De Lucia

William Sloane Muscroft

Michael O Dion

Larry R Valentine

Derrel G Gurley

Colin M MacRae

Denis C Desranleau

A high temperature packer () force a tubular string in a well, and includes a packer mandrel () and an elastomeric packer body () positioned circumferentially about the mandrel. An upper packer head () and a lower packer head () are each positioned about the mandrel and secured to an end of the packer body. A connector () axially interconnects at least one of the upper packer head and lower packer head to the packer mandrel, and a temperature responsive member () maintains the connector in position to secure the packer head to the mandrel until the temperature in the well rises to a level such that the responsive member yields to allow the connector to release the packer head from the mandrel.

High temperature packer and method

A float collarincludes a housingand a generally sleeve-shaped elastomer. The lower plateand an upper plateare each supported on an elongate rod, and at least one of the plates is axially fixed relative to the tubular housing. The plate intended for exposure to fluid pressure includes a plurality of arcuate flow portsfor communication with the annulus between the tubular housing and the elastomer prior to swelling of the elastomer.

Float collar and method

A well has a vertical casing with a window, and a lateral wellbore which communicates with the window, and which may have a casing or liner. A window assembly aligned with the window has respective passageways for first and second tubing strings, and has a concave surface for deflecting the first tubing string out into the lateral wellbore. The passageway for the second tubing string has a portion which is inclined at a very small angle with respect to a vertical centerline of the vertical casing. As the first tubing string is run into the vertical casing, a rotational locator is releasably coupled thereto by a soft release coupling mechanism. After the locator effects rotational orientation, the coupling mechanism is released and then permits the first tubing string to move therepast without damage. A seal assembly on the first tubing string is covered by a protective sleeve as it is inserted into the well, and exits the protective sleeve after entering the lateral wellbore.

Method for running two tubing strings into a well

The present invention provides a space-out compensating apparatus and method for sequentially and simultaneously landing an anchor seal assembly into a previously run downhole packer, and landing a tubing hanger into a wellhead, so that the integrity of the seals in the anchor seal assembly of the tool is not compromised, and the completion can be concluded in a single run.

Telescoping tool

A multi-lateral well has a casing, and has lateral wellbores which communicate with the casing through respective windows. A tool at the end of a coiled tubing string is introduced into the well, while disposed in a tool receiving recess of an auxiliary member that is releasably coupled against upward movement relative to the tool. At a selected vertical position within the casing, the auxiliary member is secured against further downward movement, and the releasable coupling is then interrupted to permit the tubing string to move downwardly with respect to the auxiliary member. The auxiliary member may have an inclined surface to deflect the tool into a lateral wellbore. When use of the tool is completed, the tubing string with the tool thereon is moved upwardly, and an arrangement is provided to limit upward movement of the tool relative to the auxiliary member, so that the tool and the auxiliary member are simultaneously withdrawn from the well.

Method and apparatus for one-trip insertion and retrieval of a tool and auxiliary device

An inflatable packer with a packer body, an inflatable bladder mounted around the packer body, a bladder support mounted around the inflatable bladder, the packer body, the inflatable bladder and the bladder support made of drillable material. A method for reclaiming a borehole extending from an earth surface into the earth, part of which is in a lost circulation zone, the method including closing off the borehole to fluid flow above the lost circulation zone by installing a packer system with an inflatable packer element and a valve apparatus in the borehole above the lost circulation zone, inflating the inflatable packer element with cement, and allowing the cement to set so that the inflatable packer and the valve apparatus effectively seal off the borehole to fluid flow.

Drillable inflatable packer and methods of use

A self-locating reentry system is provided to allow reliable reentry from a primary wellbore into one or more secondary wellbores. The reentry system may include one or more self-locating assemblies which may be engaged with selected portions of a lateral opening disposed between the primary wellbore and a respective secondary wellbore. Each self-locating assembly and respective key or lug cooperate with each other to provide optimum location and alignment relative to the lateral opening for communication of well tools and smaller diameter tubing strings between the primary wellbore and the associated secondary wellbore. A retaining mechanism is preferably provided to maintain the locator lug or key in its first retracted position until the reentry system is at a desired downhole location relative to the selected lateral opening.

Self-locating reentry system for downhole well completions

A straddle tool is disclosed which ensures sequential setting of the packing elements through the use of lost motion mechanisms. Once the lower pack-off has been set, the upper one is set and an internal valve is opened to allow flow through the tool to actuate a downhole tool, such as an inflatable packer. An anchor prevents actuation of the pack-off tool unless it is extended into a profile for support of the tool. Inadvertent settings of the pack-off tool are prevented, such as in oversized casing where the anchors are already fully extended, by virtue of a distance-sensing mechanism on the tool. When a large distance is sensed by one or more sensors, the mandrel is locked to the setting collars, preventing relative movement which could set the pack-off elements.

Horizontal inflation tool selective mandrel locking device

A pressure limit valve for well tools where a valve member is moveable between a first closed portion, an open position and a second closed position. A spring for closing the valve is separated from a locking chamber which contains locking elements. The locking elements are located in a locking chamber and are held deactivated by a release sleeve which separates from the valve member in an open position. When the valve moves to the second closed position it is locked by engagement of the locking elements with a stop shoulder. In use between closely coupled inflatable packers, the valve prevents trapped pressure between the packers from affecting operation of the packer valve.

Valve for inflatable packer system

A subsea packer system for large diameter casings where an inflatable liner is connected in a string of casing and has an inner tubular drillable insert member with a longitudinal bypass passage. A string of tubing with a releasable running tool is connected to a casing well head on the casing for transport into a well bore and has an isolation seal member for closing off inflation ports which extend through the insert member to the inflatable packer. The bore of the insert member is sized to a bore diameter less than the bore diameter of the casing well head and is less than the diameter of the casing.

Subsea inflatable packer system

A stage valve with particular use in cementing a well bore annulus where the stage valve has pressure operated valve member for opening a flow passage in the stage valve and the valve member has differential pressure areas which maintain the valve member open while a fluid moves through the flow passage in one direction and which can be closed by fluid moving in an opposite direction. The flow passage has a choke to develop a pressure differential from the flow of fluid. Spring members can be used with the valve member to close the flow passage when the pressure differential of the fluid flow in one direction is insufficient to maintain the valve member in an open position.

Hydraulic port collar

A system for inflating an inflatable packer located in a well bore on a liner where the inflatable packer has an inflation valve and a latching recess. An inflation tool with inner and outer assemblies is disposable by a string of tubing to a position within the inflatable packer where cup members on the outer assembly straddle the inflation valve and friction drag block members on the outer assembly are located in an annular recess above the inflation valve. An automatic J-slot interconnects the inner and outer assemblies so that the inner assembly can be repetitively moved between an intermediate, a lower and an upper location to open and close flow ports for a valve in the inner and outer assemblies with the value being in fluid communication with the inflation packer in the lower location and where the drag blocks are locked into the recess while the inner assembly is in the lower location and where the valve is closed in the intermediate and the upper locations; so that multiple inflations of multiple inflatable packers can be accomplished with one trip in the well bore.

Horizontal inflatable tool

A stage valve with particular use in cementing a well bore annulus above an inflatable packer located in a well bore on a liner where the stage valve has pressure operated outer sleeve members for opening a flow port in the stage valve and an inner sleeve member actuated by the trailing plug behind a liquid cement slurry to close the flow port whereupon spring members act on at least one of the outer sleeve members to close off the flow port on the exterior of the stage valve.

A process for determining suitable parameters of temperature and/or pressure to use in a cementing operation in a wellbore to obtain a positive seal of cement in an annulus between a liner and a borehole wall after the cement has set up and where the process utilizes the parameters of differential temperature in a well bore, pressure on the cement to obtain a positive borehole wall stress (and positive seal) in a cementing operation.

Growing community of inventors

Houston, TX, United States of America

Robert T Brooks