Weatherford Technology Holdings, LLC

Weatherford/lamb, Inc.

Corning Optical Communications LLC

Cesar G Garcia

David Ward

Patrick James Zimmerman

Antonio Bermea Flores

Dick Salomon Gonzalez

Clayton R Andersen

James Alan Rochen

Jason J Brasseaux

Ryan R Bacsik

Michael Dedman

Alison Grogan

Matthew Priesmeyer

Iain M Greenan

Lev Ring

Douglas Farley

Charles D Parker

Jobby T Jacob

William J Giraud

Brandon C Goodman

Iain Greenan

Michael Joseph Sessa

Scott Crowley

Luke Richey

Scott Williamson

Raymond Shaffer

Michael W Cast

Todd E Mitchell

Michael Shane Larisey

Christopher D Palmer

Daniel A De Clute-Melancon

Jamie Inglesfield

Tharinda Wickramasinghe

Clayton R Anderson

Stephen G Bloodworth

Patrick J Zimmermann

Charles Parker

Antonio B Flores

Dick S Gonzalez

Patrick J Zimmerman

Matthew Preismeyer

David G Ward

Douglas B Farley

James F Wilkin

A downhole tool with a radially expandable sealing element, such as a packer or plug. The sealing element employs metallic support rings disposed on the sealing element outer surface for preventing extrusion during run-in and for clamping the sealing element to the tool.

Sealing element support rings for downhole packers

A completion apparatus for a wellbore includes several flow tools and an actuation mechanism. The flow tools have a piston defining first and second chambers with a housing. The chambers communicate with hydraulics so the piston are movable in response to the communicated hydraulics. A sleeve disposed in the housing is movable with the piston between first, second, and third positions. The sleeve can have a seat movable between two conditions for passing/engaging plugs. The sleeve in the first position closes off communication through the first and second ports, and the sleeve in the second position permits communication through the first port and closes off communication through the second port. The sleeve in the third position closes off communication through the first port and permits communication through the second port. The actuation mechanism is operable to communicate the hydraulics respectively with the chambers of the flow tools.

Hydraulically actuated fluid communication method

An apparatus and method are disclosed for wet shoe applications in cementing tubing in a wellbore. A wet shoe tool has a seat and an insert in a flow bore of the tool. A first wiper plug is deployed down the tubing at least behind the cement and seats on the insert, which can then be moved in the flow bore to a bypass position allowing for fluid flow through the tool to produce a wet shoe track. A second plug is deployed down the tubing behind the second plug and seats on the seat in the flow bore of the tool. The seated second plug isolates applied pressure from passing downhole end of the tool so the integrity of the tubing can be tested. The second plug is self-removable (e.g., dissolvable) in the tool to reestablish fluid communication through the flow bore of the tool.

Apparatus and method for wet shoe applications

A downhole tool is responsive to passing objects and applied fluid pressure. A plugless valve in the tool is operable from an unobstructed condition to an obstructed condition unobstructing the tool's bore to an obstructed condition obstructing the tool's bore to the applied fluid pressure. An indexer counts the objects passing through the tool's bore and permits operation of the plugless valve from the unobstructed to the obstructed condition in response to the counted number. The applied fluid pressure in the bore obstructed by the plugless valve can then communicate outside the tool via at least one port. The plugless valve can have a movable insert that moves relative to a flapper. The indexer can use ratcheting dogs, collet, J-slot, electronic sensor, and other components to count the passing objects.

Indexing stimulating sleeve and other downhole tools

A completion apparatus for a wellbore includes several flow tools and an actuation mechanism. The flow tools have a piston defining first and second chambers with a housing. The chambers communicates with hydraulics so the piston are movable in response to the communicated hydraulics. A sleeve disposed in the housing is movable with the piston between first, second, and third positions. The sleeve can have a seat movable between two conditions for passing/engaging plugs. The sleeve in the first position closes off communication through the first and second ports, and the sleeve in the second position permits communication through the first port and closes off communication through the second port. The sleeve in the third position closes off communication through the first port and permits communication through the second port. The actuation mechanism is operable to communicate the hydraulics respectively with the chambers of the flow tools.

Hydraulically actuated fluid communication mechanism

A method and apparatus generally concerning the treatment of hydrocarbon-bearing formations adjacent a wellbore. In one embodiment, fracturing jobs are performed through the use of subs disposed in a casing string having profiles that interact with profiles formed on retractable keys of a tool.

Method and apparatus for treating a wellbore

A method concerning the treatment of hydrocarbon-bearing formations adjacent a wellbore. In one embodiment, fracturing jobs are performed through the use of subs disposed in a casing string having profiles that interact with profiles formed on retractable keys of a tool.

The present invention generally concerns the treatment of hydrocarbon-bearing formations adjacent a wellbore. In one embodiment, fracturing jobs are performed through the use of subs disposed in a casing string having profiles that interact with profiles formed on retractable keys of a tool.

A downhole tool for treating a zone adjacent a wellbore, comprising a body having at least two separable portions, the portions operable to open and close a fluid path through the tool, and at least one manipulator, like a spring-loaded finger, to establish a fluid path between an interior and exterior of the wellbore, thereby permitting a zone adjacent the wellbore to be treated. In another embodiment a method is disclosed for treating a zone of interest adjacent a wellbore.

Method and apparatus for hydraulic fracturing

A sliding sleeve opens with a deployed ball. The sleeve has a seat disposed in the housing, and the seat has segments biased outward from one another with a C-ring or other biasing element. Initially, the seat has an expanded state in the sliding sleeve so that the seats segments expand outward against the housing's bore. When an appropriately sized ball is deployed downhole, the ball engages the expanded seat. Fluid pressure applied against the seated ball moves the seat into the inner sleeve's bore. As this occurs, the seat contracts, which increases the engagement area of the seat with the ball. Eventually, the seat reaches the shoulder in the inner sleeve so that pressure applied against the seated ball now moves the inner sleeve in the housing to open the sliding sleeve's flow port.

Sliding sleeve having contracting, ringed ball seat

A sliding sleeve opens with a deployed ball and applied pressure and is subjected to reverse flow pressure. The sleeve has a housing and an insert. The housing defines a first bore and defines a flow port communicating the first bore outside the housing. The insert is disposed in the first bore of the housing and has a seat held in a first direction therein. The seat engages the deployed plug in the first direction, and the insert moves, by the applied pressure against the plug engaged in the seat, axially in the first direction inside the first bore from a closed position toward an opened position relative to the flow port. The seat is disengageable from the insert in a second direction opposite to the first direction by the reverse flow and is passable at least out of the insert.

Sliding sleeve having retrievable ball seat

Sliding sleeve having deformable ball seat

A device comprising multiple sliding sleeves actuated using same-sized balls has a resettable seat in an upper sliding sleeve and a non-resettable seat in a lower sliding sleeve. A dropped ball seats on the resettable seat forming a seal. Pressure applied from the surface shifts the resettable seat and an insert. Upon being shifted, the resettable seat releases the ball, which then moves downward to the lower sliding sleeve where the ball lands on the non-resettable seat and shifts the insert. After the first ball is released from the upper sliding sleeve, a biasing device shifts the insert whereby the seat is reset to catch the next ball. A second same-sized ball may then be dropped and land on the now reset first seat to further shift the first insert.

Resettable ball seat

A system of sliding valves wherein the inserts of multiple sliding valves may be shifted to an open position using a single shifting ball. Each individual sliding valve has a movable insert that, depending upon the position of the insert within the sliding valve, may either block or permit fluid to radially flow between the interior and exterior of the sliding valve. The insert has a profile about the interior of the movable insert allowing a shifting tool to connect to and move the insert so that fluid may be prevented from entering the interior portion of the sliding sleeve.

Multiple shift sliding sleeve

Growing community of inventors

Houston, TX, United States of America

Cesar G Garcia