Weatherford/lamb, Inc.

Antelope Oil Tool & Mfg. Co.

Innovex Downhole Solutions, Inc.

Ncs Oilfield Services Canada, Inc.

Patrick G. Maguire

Khai Tran

Clayton Plucheck

J. Eric Lauritzen

Caswell D., III Vickers

Jean P Buytaert

Ira Eugene Hining

Patrick Glen Maguire

David Michael Haugen

John C Vicic

J Eric Lauritzen

Christopher J Cuffe

Ken Whanger

Doug Durst

Guy LaMont McClung, Iii

Robert Joe Coon

Clark E Robison

David J Brunnert

Frederick Thomas Tilton

Marty Stromquist

Paul James Wilson

Robert T Brooks

Charles Gerard Brunet

Brent James Lirette

Neil A A Simpson

Michel Bouchard

Thad Joseph Scott

Mark Lewis Wyatt

Jeffrey Kubiak

Michael Lynn Betik

Pat Williamson

Caswell D Vickers, Iii

Iii Vickers Caswell D

A method of forming a centralizer where a flat plate is created into a tubular where the flat plate is typically rolled so that two sides of the plate contact one another and are then linked, typically by welding. Openings are then created in the tubular such that there are no corners or other points that stress cracks may originate. Once the openings are created the remaining material between adjacent openings forms ribs. The openings created in the tubular are generally aligned with the long axis of the tubular. The material at the upper and lower end of the flat plate where openings were not created serve as circumferential collars. The ribs may be radially outwardly expanded in order to provide adequate stand-off. In many instances the ribs will also be hardened by heat treating or other hardening processes.

Rolled tubular centralizer

A stop collar for a tubular and method for installing a stop collar on a tubular. The stop collar includes a flexible member extending circumferentially around the tubular more than once. A tension force on the flexible member causes the flexible member to apply a radially-inward gripping force on the tubular. The stop collar may also include a shield disposed around at least a portion of the flexible member, to protect the flexible member in a downhole environment. The stop collar may also or instead include an adhesive disposed radially between the flexible member and the tubular.

Wrap-around stop collar and method of forming

Apparatus, methods, and systems for preconditioning and/or testing a centralizer, and a preconditioned centralizer, are provided. The apparatus includes a restrictor positionable around a tubular and having an inner diameter that is greater than an outer diameter of the tubular. The apparatus also includes a driver configured to translate the restrictor relative to the tubular in at least a first axial direction. The restrictor is configured to engage a centralizer attached to the tubular, and the restrictor is configured to at least partially collapse flexible ribs of the centralizer when the driver axially translates the restrictor across at least a portion of the flexible ribs.

Centralizer preconditioning and testing apparatus and method

A centralizer for centralizing a tubular in a wellbore, and a method of manufacturing a centralizer. The centralizer may include a plurality of ribs spaced circumferentially apart from one another around the tubular. Each of the ribs may include a first end section, a second end section, and a middle section extending between the first and second end sections. A first plurality of spacers may be spaced circumferentially apart from one another around the tubular. Each of the first plurality of spacers may be positioned circumferentially between two of the plurality of ribs. The first plurality of spacers and the first end sections of the plurality of ribs may be axially aligned and together at least partially define a first end collar.

Multi-vane centralizer and method of forming

An attachment apparatus for attaching to a tubular. The apparatus may include a flexible member extending circumferentially around the tubular more than once. A tension force on the flexible member may cause the flexible member to apply a first radially-inward gripping force on the tubular. An annular sleeve may be positioned radially-outward from the flexible member. The sleeve may apply a second radially-inward gripping force on the flexible member and the tubular.

Wrap-around band and sleeve attachment apparatus for an oilfield tubular

A method and apparatus for completing a wellbore junction, wherein, in one embodiment, a first leg of a screen is fastened within a first tubular with a preformed window. The first tubular houses a whipstock with a cut-out portion containing a folded second leg of the screen. The first tubular is lowered into a junction of a central and a lateral wellbore. A second tubular is lowered within the first tubular and catches an end of the folded second leg of the screen thereby unfolding and expanding the screen as the second tubular is guided into the lateral wellbore.

Apparatus and methods to complete wellbore junctions

An expander tool for expanding a first tubular into a second surrounding tubular within a wellbore. The expander tool first comprises a body. Within the body is an expansion member capable of being actuated outwardly from the body when expansion of the first tubular is desired. In one aspect, the expander tool is a rotary expander tool, and the expansion members define a plurality of rollers. The expander tool further comprises at least one sensor for sensing a downhole condition during expansion of the tubular. The sensors in one aspect include at least one tool for sensing wall dimensions of the first tubular such as inner diameter or wall thickness. Examples include sonic logs, caliper logs, and electromagnetic wall thickness tools. A depth gauge may also be included. In one aspect, a data transmission device is provided between a surface server and the sensors downhole. In this way, the operator at the surface can monitor progress of the expansion operation downhole.

Expander tool for downhole use

The present invention generally relates to an apparatus for sealing a wellbore. The sealing apparatus includes an expandable tubular body having one or more sealing elements disposed thereon. In one aspect, the sealing elements include swelling and non-swelling sealing elements. Preferably, the swelling sealing elements are made of a swelling elastomer capable of swelling upon activation by an activating agent. The swelling elements may be covered with a protective layer during the run-in. When the tubular body is expanded, the protective layer breaks, thereby exposing the swelling elements to the activating agent. In turn, the swelling elements swell and contact the wellbore to form a fluid tight seal.

Expandable sealing apparatus

The present invention provides apparatus and methods for controlling and/or powering downhole components without the need for control and/or power lines extending from the components to the surface of the well and without the need for power or control lines to be inserted into the wellbore along with the components. In one aspect of the invention, a borehole is lined with a casing, the casing having at least one aperture disposed. Adjacent the aperture, on the outer surface of the casing, is a docking station, which is permanently attached to the casing and includes a socket. After the casing is installed in the borehole, a downhole component can be lowered into the wellbore. The downhole component is equipped with a connector extending from an outer surface thereof. The connector assembly is disposable through the aperture in the casing and, the connector assembly can be connected to the socket of docking station.

Docking station assembly and methods for use in a wellbore

A connector arrangement used for connecting a first tubular to a second tubular. The first tubular member has at least one circumferential ring profile, and the second tubular member has a corresponding number of matching circumferential ring profiles. When the ring profiles of the two tubulars are mated and interlocked, they form separate and independent fluid seals as well as a mechanical lock able to hold the tubulars together during future expansion of the entire tubular and joint. Further, selecting properties of the tubulars such as yield strength and modulus of elasticity or constraining a diameter of one of the tubulars during expansion or compression forms a tight connection due to elastic recovery of the tubulars.

Method of jointing and running expandable tubulars

An improved expansion assembly for an expander tool is provided. The expander tool is used to expand a surrounding tubular body within a wellbore. Accordingly, a method for expanding a surrounding tubular is also provided. The expansion assembly first comprises a piston disposed within a recess of the expander tool. The top surface of the piston closely receives a pad. The pad is held in close proximity to the top surface of the piston such that it does not rotate about a shaft. This arrangement reduces the geometric size of the expansion assembly, affording a larger inner diameter for the hollow bore of the expander tool itself. At least one reinforcement member is disposed on or within the pad to strengthen the pad during an expansion operation. The reinforcement member is fabricated from a durable material, and is arranged along the pad in the area of contact with the surrounding tubular during an expansion operation.

Expansion assembly for a tubular expander tool, and method of tubular expansion

An apparatus and method for expanding a lower string of casing into frictional contact with an upper string of casing, and thereby hanging the lower string of casing onto the upper string of casing is provided. The apparatus essentially defines a lower string of casing having a separation region formed in the top end thereof. The lower string of casing is run into the wellbore, and positioned so that the top end overlaps with the bottom end of an upper string of casing already cemented into the wellbore. The top end of the lower casing string is expanded below the depth of the separation region into frictional contact with the upper string of casing. At the same time, or shortly thereafter, the top end of the upper string of casing is expanded. As the portion of the lower casing string having the separation region is expanded, the casing severs into upper and lower portions. The upper portion can then be removed from the wellbore, leaving a lower string of casing expanded into physical contact with an upper string of casing. The separation region may be formed by heat treating the tubular at the point of desired severance. In another aspect, the separation region may comprise the connection between two tubulars. This involves connecting two tubulars to form the tubular to be expanded downhole. The tubular formed is then lowered into the wellbore and expanded at the connection to separate the tubular.

Method and apparatus for expanding and separating tubulars in a wellbore

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.

Growing community of inventors

Tomball, TX, United States of America

Clayton Plucheck