Baker Hughes Corporation

Chevron U.s.a. Inc.

Baker Oil Tools, Inc.

Welldynamics, Inc.

Exxon Production Research Company

Centergenics, LLC

Production Sciences, Inc.

Richard Paul Rubbo

Napoleon Arizmendi

Brett W Bouldin

Mark Hiroshi Yamasaki

Douglas Julius Lehr

Alfred R Curington

Merle L Bell

Daniel S Bangert

Richard L Forehand

David Michael Haugen

Mike A Luke

Timothy Rather Tips

Manuel Eduardo Gonzalez

Mitchell Carl Smithson

M Clark Thompson

Edward J Kossa

Rafael Ramirez

Frank X Mooney

Charles H Webb

F T Tilton

Forrest Howard

A A Mullins

Dan Purkis

Scott Carpenter

David King Anderson, Ii

William D Moody

Mitcell Carl Smithson

David King Anderson

Mark H Yamasaki

Ii David King Anderson

A tubular gripping device comprising an outer body, a self-locking mechanism, and a retainer member. The outer body defines an inner tubular cavity having a first inner diameter, a second inner diameter, a first load shoulder, and a second load shoulder. The first load shoulder tapers the first inner diameter down to second inner diameter at the second load shoulder. The second load shoulder acts as a stop at the second inner diameter. The self-locking is mechanism positioned substantially co-axially within the tubular cavity of the outer body and proximate the first inner diameter, the self-locking mechanism having a spring expanded and a spring released position. The retainer member has a first retainer position radially restraining the self-locking mechanism in the spring expanded position and a second retainer position allowing the self-locking mechanism to contract to the spring released position to grip an outer surface of a tubular member.

Tubular gripping device

Systems and processes are provided for removing fluid from a subterranean well and enhancing the production of oil and/or gas are herein disclosed. In one embodiment, the system includes an injection conduit, an injection valve, a relief valve, a container, a container valve, a return conduit valve, and a return conduit, all arranged within a subterranean well for removing at least one fluid from the well. The removal of at least one fluid from the well is controlled by the flow of gas into the injection conduit.

Processes and systems for treating oil and gas wells

The present invention discloses an improved system for measurement of the liquid flow rate and totalized liquid production of a producing well. In the method of the present invention, liquid production rate in a pumping well is determined by calculation based upon wellbore geometry and continuously monitoring the depth of the fluid level within the wellbore. It is applicable to any pump lifted well where it is possible to shut the pump off periodically. Accuracy is enhanced with this method by properly accounting for pump leakage and where pump leakage is either known or can be estimated within reasonable limits or where it is measured during the pump shut off cycle.

System and method for measuring well flow rate

Various embodiments of the present invention disclose enhanced and improved well production tools for increasing the stability of production zones in a wellbore. Various embodiments of the present invention generally relate to apparatuses, systems, and processes for efficiently and effectively isolating zones within a wellbore.

Fracture valve tools and related methods

Blapper valve tools and related methods

A packer element for use in forming a fluid pressure barrier within a wellbore. The packer element uses a thermoplastic component to accomplish the seal against the interior diameter of a surrounding tubular and an energizing component that is preferably formed of elastomeric material. The thermoplastic component of the packer element provides a sealing surface and defines an energizing chamber within. An energizing chamber is defined within the thermoplastic component and contains energizing elements that, when axially compressed, will urge the sealing surface of the thermoplastic component into sealing engagement with the surrounding tubular.

Energized thermoplastic sealing element and method of use

A multi-line back pressure control system for providing two way hydraulic line movement while maintaining back pressure control. Check valves are integrated in hydraulic fluid control lines extending downhole into a wellbore. Each check valve is pilot operated with pressure from another hydraulic line to selectively open the lines for two way fluid communication. Removal of the pilot pressure closes the check valves to provide passive back pressure control against catastrophic wellbore events. Pilot pressure operation between multiple pressurized lines can be provided with valves such as three-way, three-position piloted valves.

Multi-line back pressure control system

A system for transmitting hydraulic control signals or hydraulic power to downhole well tools while significantly reducing the number of hydraulic lines required. Hydraulic control signals are furnished at relatively low pressures to actuate a selected well tool, and the hydraulic pressure is selectively increased over a threshold level to provide hydraulic power to the well tool. The hydraulic control actuation signals can be controlled by selectively pressurizing different hydraulic lines in a selected sequence and by selectively powering the fluid pressure within a selected hydraulic line. The combination of selective sequential actuation and selective fluid pressure provides multiple actuation combinations for selectively actuating downhole well tools. Additional combinations can be provided by changing the pressurization sequence, magnitude, absolute time, duration, and pressurization profile within a discrete time period.

Multiplier digital-hydraulic well control system and method

Method and apparatus for actuating one or more downhole well tools carried by a production or work string conduit having an imperforate wall and for blocking fluid communication between an activating fluid body and a second fluid source within said well across dynamic seals between actuating members of the well tool, by producing selective signals through the conduit wall detectable by a member to produce an activating signal for actuating the downhole well tool by a downhole energy source.

Subsurface well apparatus

A pack-off tubing hanger is shown for use in a tubing string extending from a well surface location to a downhole location within a well casing. The hanger body includes an external packing element and gripping slips which support the hanger body within the surrounding casing. A hydraulic line communicates hydraulic pressure from the lower end of the hanger to a setting chamber to hydraulically set the packing elements and actuate the gripping slips. The tubing hanger is releasable by a straight upward pull upon the tubing string extending from the well surface to the tubing hanger.

Pack-off well apparatus with straight shear release

An apparatus and method are provided for telescopically retracting a subterranean well tubing carried perforating gun. The retracting apparatus comprises a cylindrical housing which is carryable into the well on a tubular conduit, such as a work string, production string, or the like. A first chamber is provided within the housing and contains a body of fluid. Telescoping piston means are selectively releasably locked relative to the housing. A second chamber is in selective fluid flow communication with the first chamber. Means in communication with the piston means are provided for carrying the perforating gun. Means for communicating well pressure to the piston means are actuated upon firing of the gun. Means are provided for transferring the body of fluid from the first chamber to the second chamber, whereby during such transferring, the perforating gun is telescopically retracted relative to the housing.

Method and apparatus for selective retraction of a tubing carried

A subterranean well casing float tool has a tubular metal housing which is securable to well casing conduit. A valve is carried within the housing and comprises a frame with a valve head and seat carried relative to the frame and biased toward closed position. A compartment includes the valve head for enclosure around a bias, such as a spring, when the valve head is moved away from the valve seat. The valving components are directly secured to the housing by threads having profiled shear surfaces such that the shear area of the valving members is substantially greater than that of the housing.

Subterranean well casing float tool

An apparatus and method are provided for completion of a horizontal section of a subterranean well. The apparatus comprises a first packer assembly which is settable in the well by longitudinal manipulation of a tubular workstring. A second packer is carried into the well on the workstring and is settable by application of hydraulic pressure through the workstring. A perforating gun is carried into the well on and in communication with the workstring, together with a gun retractor for telescopically retracting the perforating gun. A valve is also provided for selective communication between the exterior and the interior of the apparatus and is manipulatable to the open position to effect, for example, a fluid flow path from the production zone to the top of the well for transmission of production fluids in the well.

Method and apparatus for completion of a well

A packer assembly is provided for use in a subterranean well and settable only by longitudinal manipulation of a tubular workstring. The assembly has an outer housing and a seal assembly with anchoring slips carried by the housing in retracted position and movable to expanded position along the wall of a casing or the like. A longitudinally extending central mandrel telescopes within the housing. Orienting and setting pins are provided for initial receipt within orienting and setting slots with the setting pins being moved to the orienting slot to permit setting of the packer. The seal assembly and anchoring slips are maintained in retracted position and are responsive to a variation in internal diameter between a first and second tubular conduit to thereafter permit the manipulating device to move the seal assembly and the anchoring slips to expanded position within only the second tubular conduit which has a diameter less than that of the first tubular conduit.

Growing community of inventors

The Woodlands, TX, United States of America

Richard Paul Rubbo