Weatherford/lamb, Inc.

Weatherford Technology Holdings, LLC

Precision Tube Technology, Inc.

Watherford/lamb, Inc.

Robert J. Coon

Roddie R. Smith

Robert P. Badrak

Patrick G. Maguire

Robert P Badrak

Frederick Thomas Tilton

Robert Joe Coon

Roddie Robert Smith

Patrick G McGuire

David Michael Haugen

Karsten Heidecke

David J Brunnert

Kevin Leon Gray

Michael W Hayes

Neil A A Simpson

Doyle Fredric Boutwell, Jr

Joseph Ross Rials

David J Havens

Ken Whanger

Richard Lee Giroux

Simon John Harrall

Neil Andrew Abercrombie Simpson

Albert C Odell, Ii

Paul David Metcalfe

Tuong Thanh Le

Gary Thompson

Patrick Glen Maguire

David Graham Hosie

Alexander Craig Mackay

Gregory Guy Galloway

Ghazi J Hashem

John Richard Setterberg, Jr

Merle Edward Evans

J Eric Lauritzen

Simon J Harrall

Christopher J Cuffe

Deborah Lynn Banta

Mark S Fuller

William R Howie

Lawrence W Smith

Jeffery Bode

Raymond C Rowland

James R Hyde

Garry F McClelland

Sergey Kolesov

Merle E Evans

Jr Setterberg John Richard

Robert J Coon

Using an X-ray diffractometer, a processing device, and memory, a database models estimates of a number of cycles to failure for each of a plurality of materials. The model estimates are performed on the material at a plurality of applied fatigues up to a failure point and are based on parameters including residual stress, the micro-strain, and the ratio between X-Ray peak intensity and background intensity of the component material. To inspect a component, the material of the component is selected in the database, and measurements are obtained at two or more different depths of at least a portion of the component. Information about current residual stress, micro-strain, and ratio between X-Ray peak intensity and background intensity are determined from the obtained measurements. Then, a fatigue life of the portion of the component is estimated by matching the information to at least one of the modelled estimates of the number of cycles to failure in the database for the selected material.

X-ray based fatigue inspection of downhole component

A slip component for a downhole tool has a bearing surface that is hard surface treated. The slip component, which can be a slip or other component of a slip mechanism used on a packer, bridge plug, or other downhole tool, is composed of a non-metallic base material, such as plastic, composite, or ceramic. To hard surface treat the slip component, at least the bearing surface is positioned relative to an ion sputtering apparatus. An intermediate layer is first bonded onto the bearing surface by ion sputtering an intermediate material onto the non-metallic base material of the slip component. Then, the bearing surface of the slip component is positioned relative to an electrosparking apparatus, which has an electrode composed of a selected external material for depositing on the slip component. Using the electrosparking apparatus, an external layer is bonded at least on the bearing surface.

Hard surfacing non-metallic slip components for downhole tools

A bearing surface of an oilfield component is treated by applying a surface treatment having a low coefficient of friction to the bearing surface of the oilfield component by weld fusing an overlay of a Cu&#x2014;Ni&#x2014;Sn alloy material to the bearing surface. Weld fusing the overlay of the Cu&#x2014;Ni&#x2014;Sn alloy material to the bearing surface can involve laser surface cladding the overlay of the Cu&#x2014;Ni&#x2014;Sn alloy material to the bearing surface, gas tungsten arc welding the overlay of the Cu&#x2014;Ni&#x2014;Sn alloy material to the bearing surface, or plasma tungsten arc welding the overlay of the Cu&#x2014;Ni&#x2014;Sn alloy material to the bearing surface.

Cu&#x2014;Ni&#x2014;Sn alloy overlay for bearing surfaces on oilfield equipment

A slip component for a downhole tool has a bearing surface hard surface treated. The slip component, which can be a slip or other component of a slip mechanism used on a packer, bridge plug, or other downhole tool, is composed of a metallic base material such as magnesium, aluminum, an aluminum alloy, or a magnesium alloy. To hard surface treat the slip component, at least the bearing surface is positioned relative to an electro sparking apparatus. Using the electrosparking apparatus, an external layer is bonded at least on the bearing. In a further embodiment, an intermediate layer can be first bonded onto at least the bearing surface by ion sputtering an intermediate material onto the metallic base material of the slip component. Then, an external layer can be bonded at least on the intermediate layer by electrospark deposition.

Hard surfacing metallic slip components for downhole tools

A pipe handling system for locating a pipe joint in a joining assembly that includes an internal joining tool and an external joining tool is provided. The system includes a gripper configured to grip a surface of the pipe joint; an elevator configured to pick up the pipe joint and position the pipe joint adjacent a string of pipe disposed in the external joining tool; and a deployment assembly coupled to the gripper, wherein the deployment assembly includes a cable that is used to position the internal joining tool inside the pipe joint.

Pipe handling system

The present invention generally relates to a pipe handling system for use with a tubular joining system. In one aspect, a method of forming a string of pipe using a joining assembly at a wellbore is provided. The joining assembly includes an internal joining tool and an external joining tool. The method includes the step of picking up the pipe joint using an elevator. The method further includes the step of positioning a lower end of the pipe joint adjacent an end of a string of pipe disposed in the external joining tool. The method also includes the step of moving the internal joining tool from a first position to a second position relative to the elevator, wherein the second position is between the pipe joint and the string of pipe. The method further includes the step of forming a connection between the pipe joint and the string of pipe.

A tubular configured to mate with a second tubular so that sealing integrity is maintained between the tubulars before, during, and after expansion of the tubulars is disclosed. In one embodiment, a connector for connecting tubulars is provided. The connector includes a pin portion; a box portion, wherein the pin and the box portions are configured to mate; a sealing surface formed in an inner surface of the box portion; a seal disposed in a groove formed in an outer surface of the pin portion, wherein the seal is configured to engage with a sealing surface of the box portion upon mating of the pin and the box portions; and a bump formed on an inner surface of the pin portion, wherein the bump is substantially radially aligned with the groove and the bump is configured so that the seal remains engaged with the box portion during and after expansion of the pin and the box portions.

Energizing seal for expandable connections

Apparatus and methods are provided for reducing drilling vibration during drilling with casing. In one embodiment, an apparatus for reducing vibration of a rotating casing includes a tubular body disposed concentrically around the casing, wherein tubular body is movable relative to the casing. Preferably, a portion of the tubular body comprises a friction reducing material. In operation, the tubular body comes into contact with the existing casing or the wellbore instead of the rotating casing. Because the tubular body is freely movable relative to the rotating casing, the rotating casing may continuously rotate even though the tubular body is frictionally in contact with the existing casing.

Vibration damper systems for drilling with casing

A method of expanding tubing downhole comprises providing a section of expandable tubing of a first diameter, and axially compressing the tubing to induce buckling, such that the buckled portion describes a larger second diameter. The resulting diametric expansion may be utilised to anchor or seal the tubing within a larger bore. The buckled portion may be used to anchor the tubing within the wellbore prior to expansion of the length of the tubing into the wellbore.

Expanding tubing

Aspects of the present invention provide methods and apparatus for connecting two tubulars using a welding process with reduced inner diameter flash. The method includes connecting an end of a first expandable tubular to an end of a second expandable tubular using a welding process and reducing an inner diameter flash using a flash reducing device. In one embodiment, the flash reducing device is a plug disposed in the bore of the two tubulars. In another embodiment, the flash reducing device is a roller member. In a further embodiment, the flash reducing device is a rotating cutting member.

Method of mitigating inner diameter reduction of welded joints

The present invention relates to a method and apparatus for anchoring an expandable tubular within a wellbore prior to expanding the length of the expandable tubular into contact with the wellbore. An expandable system comprises the expandable tubular and a deployment tool, wherein the deployment tool exerts radial force against the expandable tubular to expand at least a portion of the expandable tubular into contact with the wellbore to anchor the expandable tubular prior to the expansion process. A method for anchoring an expandable tubular within a wellbore prior to the expansion process is also provided, wherein radial force expands the expandable tubular into contact with the wellbore to initially anchor the expandable tubular. A method for altering the shape of the anchor is also provided.

Open hole anchor and associated method

The present invention provides a liner hanger and a method of hanging a liner in a wellbore. In one aspect, a process for setting a liner in a wellbore is provided in which a tubular having a slip formed on an outer diameter of the tubular at a first location and a preformed bypass for circulating a fluid disposed at a second location is set and expanded into substantial contact with an inner diameter of the wellbore, a casing, or another liner. In another aspect, a process for setting a liner in a wellbore is provided in which a tubular having a slip formed on an outer diameter of the tubular at a first location is placed in the wellbore, a bypass for circulating a fluid is formed downhole, the liner is set and expanded into substantial contact with an inner diameter of the wellbore, a casing, or another liner. In yet another aspect, a process for creating a liner top seal is provided in which the liner is set by expanding a protrusion in an upper end of a tubular into substantial contact with an inner diameter of the wellbore, and the upper end of the tubular is then reformed and expanded into substantial contact with the inner diameter of the wellbore.

Method and apparatus for expandable liner hanger with bypass

The present invention generally relates to methods of connecting two expandable tubulars. In one aspect, the method includes flash welding the ends of the expandable tubulars together. Thereafter, the connected tubulars are lowered into the wellbore for expansion. The flash welding process provides a highly reliable joint for expansion.

Flash welding process for field joining of tubulars for expandable applications

The present invention generally relates to methods of connecting two expandable tubulars. In one aspect, the method includes flash welding the ends of the expandable tubulars together. Thereafter, the connected tubulars are lowered into the wellbore for expansion. The flash welding process provides a highly reliable joint for expansion. In another aspect, the present invention provides a method for expanding a non-uniform tubular. In one embodiment, the non-uniform tubular is formed by connecting two misaligned tubulars.

Method and apparatus for expanding a welded connection

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Sugar Land, TX, United States of America

Robert P Badrak