Halliburton Company

Halliburton Energy Services, Inc.

Lee Wayne Stepp

Don S Folds

Richard Lee Giroux

Donald R Smith

Loren C Swor

Donald W Winslow

Phillip M Starr

Gregory W Vargus

David Durward Szarka

John T Brandell

Gary D Zunkel

Paul David Ringgenberg

Steven George Streich

Kevin T Berscheidt

Kenneth Gregory Neal

Ronald L Hinkie

Roger Lynn Schultz

Alan B Duell

James C Tucker

James J Venditto

Eugene E Baker

Morris G Baldridge

Harold Otis Treece

Michael L Bolin

Joseph B Crump

Jerome F Borges

A system and method for determining load on a downhole tool according to which one or more sensors are embedded in one or more components of the tool or in a material on one or more of the components. The sensors are adapted to sense load on the components.

System and method for sensing load on a downhole tool

A downhole tool apparatus for insertion into and sealing engagement with a wellbore. The downhole tool includes upper and lower casing engaging members and an intervening sealing member. In one aspect the intervening sealing member may be a deformable material. In another aspect, the intervening sealing member may be a flowable material cured in the well bore.

Downhole sealing tools and method of use

A downhole tool apparatus for insertion into and sealing engagement with a wellbore. The apparatus comprises a tube having an expandable diameter, and a gripping member joined to the tube adapted to engage a portion of the wellbore to limit movement of the tube within the wellbore. The tube may also include a sealing member adapted to mate with the wellbore to form a sealing engagement.

A wellhead isolation tool comprises a threaded drive rod coaxially aligned with a tubular mandrel having a smooth outer surface. A motor displaces the threaded drive rod vertically without rotating the drive rod to move the tubular mandrel through a wellhead into a tubular element in a well. The lower end of the tubular mandrel will sealingly engage the tubular element in the well so that treating fluids or other substances such as, but not limited to, chemicals and erosive flows, can be displaced therethrough at high pressures into the well to fracture or otherwise treat the well without damaging the wellhead.

Screw-driven wellhead isolation tool

A downhole tool for sealing a wellbore. The downhole tool includes a packer with a ball seat defined therein. A sealing ball is carried with the packer into the well. The movement of the sealing ball away from the ball seat is limited by a ball cage which is attached to the upper end of the packer. The ball cage has a plurality of ports therethrough for allowing flow into the ball cage and through the packer at certain flow rates. A spring is disposed in a longitudinal opening of the packer and engages the sealing ball to prevent the sealing ball from engaging the ball seat until a predetermined flow rate is reached. When the packer is set in the hole, flow through the frac plug below a predetermined flow rate is permitted. Once a predetermined flow rate in the well is reached, a spring force of the spring will be overcome and the sealing ball will engage the ball seat so that no flow through the frac plug is permitted.

Frac plug with caged ball

A high temperature, high pressure retrievable packer adapted for service under extreme operating conditions when the packer apparatus is held in the wellbore with a mechanical slip and a barrel slip. The barrel slip has a barrel slip body with a plurality of openings defined in the outer surface of the body. Cylindrical inserts are received in the openings. The cylindrical inserts define upward facing and downward facing gripping edges that will engage casing when the barrel slip body is radially expanded. The inserts are preferably tungsten carbide inserts. A sufficient number of inserts are included along the length and around the circumference of the barrel slip so that the barrel slip can get a good grip in the casing wall. Separate metals may be used for the barrel slip body and the inserts so that a higher yield strength alloy steel may be utilized than is possible with other barrel slip arrangements.

High temperature high pressure retrievable packer with barrel slip

A packer apparatus for sealing between a tubing string and a casing in a wellbore is disclosed. The packer apparatus includes a seal assembly disposed about a packer mandrel. Upper and lower seal wedges are disposed about the packer mandrel above and below the seal assembly and may be inserted between the seal assembly and the packer mandrel to radially expand the seal assembly into engagement with the casing. The seal assembly includes an expandable elastomeric seal element having anti-extrusion bridge elements disposed in recesses at the upper and lower ends thereof. The anti-extrusion elements form an almost complete circle and thus are arcuately shaped having first and second ends with a gap therebetween. The anti-extrusion bridge elements are preferably automatically radially retractable elements so that when the seal wedges are removed from between the seal assembly and the packer mandrel, the automatically radially retractable anti-extrusion elements will apply a radially inwardly directed force sufficient to cause the seal assembly to radially retract and close around the packer mandrel.

Retrievable high pressure, high temperature packer apparatus with anti-extrusion system and method

Retrievable high pressure, high temperature packer apparatus with

A casing inflation packer for use in a casing string in a well bore. The apparatus includes a housing connected in the casing string. An inflatable packer portion on the housing sealingly engages the well bore when inflated. An inflation passageway is defined between a housing central opening and the packer. A rupture disc is initially disposed between the central opening and the inflation passageway for preventing communication therebetween. The rupture disc ruptures in response to a first predetermined pressure, thereby placing the central opening in communication with the packer through the inflation passageway. A slidable control valve is disposed in the inflation passageway and is initially shearably held in an open position. Upon application of a second predetermined pressure across the valve, the valve is moved to a closed position, thus preventing overinflation of the packer and also preventing deflation thereof. A check valve allows fluid to enter the packer and acts as a backup preventing fluid from leaving the packer in the event of failure of the control valve. Another check valve provides pressure equalization between the packer and the well annulus as the apparatus is lowered into the well bore. The packer has an elastomeric packer element and metal reinforcing, such as a metal packer bladder, disposed inside the packer element.

Casing inflation packer

A fracture oriented completion tool system for use in a casing string in a wellbore. The completion tool comprises a casing valve having a radioactive source therein, the orientation of which may be determined by use of a detector apparatus, such as a rotational gamma ray detector. The casing valve thus may be aligned with the fracture of a zone of interest in the well. A plurality of casing valves may be used, with at least one having a radioactive source. A swivel connection may be used to interconnect the casing valve so that housing ports therein may be aligned as the casing is run into the wellbore. In one preferred embodiment, the swivel connection is a locking swivel connection. A method of positioning a casing string in the well utilizing the completion tool is also disclosed.

Fracture oriented completion tool system

A coiled tubing operated full opening completion tool system for use in a well bore. The tool system comprises a completion tool, such as a casing valve, disposed in a well casing. The tool system further comprises a positioner tool for opening and closing a sliding sleeve in the casing valve. A hydraulically actuated operating cylinder section, including opening and closing cylinder sections, is used to actuate the positioner tool to open and close the casing valve sleeve. Hydraulic slips lock the tool in position in the well bore during actuation. The tool further comprises a jetting tool which is hydraulically actuated between an open position thereof in which fluid in the tool is communicated through a jetting nozzle aligned with a port in the casing tool and a closed position. A J-slot and lug are provided in the positioner tool for controlling the longitudinal position thereof during opening and closing of the casing valve sleeve. Another J-slot and lug are provided in the jetting tool for controlling the longitudinal position of a jetting sleeve therein for opening and closing the jetting tool. A spring in the jetting tool biases the jetting sleeve toward its closed position. The tool is specifically designed for, but not limited to, use on coiled tubing.

Coiled tubing operated full opening completion tool system

The present invention provides a cementing tool for cementing multiple stages within a well. The assembly includes a housing assembly which defines one or more cementing ports. A first sleeve assembly is retained within the housing and is movable from a first position, where the sleeve covers the port, and thereby precludes fluid flow therethrough, to a second position wherein the sleeve opens the cementing port. The apparatus also includes a second sleeve assembly which is movable from a first position away from the cementing port to a second position wherein the sleeve assembly covers the port. The first sleeve is cooperatively configured with the housing assembly to provide engaging surfaces which resist rotation of the first sleeve relative to the housing. Additionally, the first sleeve and the second sleeve assembly are configured to limit relative rotation when the two pieces are longitudinally adjacent one another.

Method and apparatus for the multiple stage cementing of a casing string

A stage cementer and inflation packer apparatus. The apparatus comprises a mandrel with an external closing sleeve and an operating sleeve interlocked therewith. Below the operating sleeve is an opening sleeve. The opening sleeve is mechanically acutated by a pump-down plug in a plug-operated embodiment or by a differential pressure acting on the opening sleeve in a hydraulically operated embodiment, to actuate the opening sleeve to allow inflation of the packer element. A back check valve prevents the packer from deflating. After the packer is inflated, additional pressure is applied which ruptures a rupture disc to open a port to the well annulus above the set packer element. Cementing may be carried out through this port, and after the cementing operating, a plug engages the operating sleeve to move the operating sleeve in the external closure sleeve, thereby closing the cementing port. After cementing is complete, the center components of the apparatus may be drilled out, leaving the external closure sleeve to permanently seal the cementing port.

Growing community of inventors

Comanche, OK, United States of America

Lee Wayne Stepp