Halliburton Energy Services, Inc.

Halliburton Company

Donald R Smith

Kevin T Berscheidt

Don S Folds

Gregory W Vargus

Lee Wayne Stepp

Donald W Winslow

Daniel Keith Moeller

Donald F Hushbeck

Paul David Ringgenberg

Loren C Swor

Jesse Cale Porter

Ronald L Hinkie

Brian Keith Wilkinson

Alton L Branch

Donny W Winslow

Shawn Ray Webb

J Tad Bohlen

Lloyd Crockford

Mike Sutton

Frank Vinicio Acosta

Matthew Todd Howell

Thomas W Hawkins

Stephen E Tilghman

Phillip M Starr

Kendall Lee Pacey

Kyle Wayne Davis

Tracy Michael Martin

Robert Preston Clayton

Ricky D Jacobi

Robert P Clayton

Anthony Valencia

Adam J Milne

Zachery Ryan Olson

David Armstrong

Aaron Jacob Miller

Seth B Thomas

Matthew Dexter

Evan Blott

Jeffrey A Jordan

Gary J Makowiecki

Donald Wayne Winslow

Lloyd A Crockford

Kendall L Pacey

An apparatus comprising a singular tubular structure to be positioned inside casing of a wellbore formed in a subsurface formation, wherein the singular tubular structure is configured to expand to contact an inner wall of the casing and provide differential pressure integrity in the wellbore while an isolating component is positioned in the singular tubular structure.

Expandable tubular structure for maintaining differential pressure integrity in a wellbore

Disclosed herein are various embodiments of an isolation device comprising a top slip, a top slip prop in engagement with the top slip, a bottom slip, a bottom slip prop in engagement with the bottom slip, a packer element positioned between the top slip prop and the bottom slip prop, wherein movement of the top slip prop and the bottom slip prop towards each other causes the packer element to expand outwardly, an annular receptacle formed between the inner mandrel and the top slip prop, and a pressure transfer sleeve at least partially disposed within the annular receptacle.

Pressure transfer sleeve for top slip retention

An isolation plug includes a ratchet wedge having a set of threads formed along an interior surface of the ratchet wedge, where the set of threads are configured to permit movement in a first direction and restrict movement in a second direction. The isolation plug also includes a ratchet shoe configured to shift in the first direction to ratchet into the ratchet wedge to engage the ratchet wedge, where the ratchet shoe has a corresponding set of threads that are configured to engage the set of threads of the ratchet wedge to permit the ratchet shoe to shift in the first direction, and restrict movement in the second direction. The isolation plug further includes a packing element positioned in between the ratchet shoe and the ratchet wedge, the packing element configured to expand radially as the ratchet shoe is shifted in the first direction.

Isolation plugs, ratchet systems, and methods to set a packing element

Dissolvable pump down devices, dissolvable pump down assemblies, and methods to propel a bottomhole assembly through a lateral section are presented. A dissolvable pump down device includes an engageable portion, and one or more expandable pieces that are initially in a first position before the dissolvable pump down device is deployed in a wellbore, and configured to expand from the first position to a second position in response to a force generated by fluid flow of fluid through the wellbore. A diameter of the expandable pieces while the expandable pieces are in the first position is less than the diameter of the one or more expandable pieces while the one or more expandable pieces are in the second position. The engageable portion and the one or more expandable pieces are configured to dissolve after the dissolvable pump down device is positioned at the desired wellbore location.

Dissolvable pump down devices, dissolvable pump down assemblies, and methods to propel a bottomhole assembly through a lateral section of a wellbore

An isolation device can include a packer element that is actuated via a slip system to engage with an inner diameter of a tubing string to set the plug. The isolation device can be a frac plug. Top and bottom slip props of the slip system can be shaped such that the packer element is inhibited or prevented from engaging with an inner mandrel after the plug has been set within a wellbore. The slip props can be self-supporting; thus, the inner mandrel can be removed from the isolation device after setting and can be reused in other downhole tools. The isolation device can be used for zonal isolation to treat a zone of interest within a subterranean formation. The treatment can be a fracturing operation.

Isolation device with inner mandrel removed after setting

A wellbore system suitable for conducting pressure testing of wellbore equipment. The system comprises a casing and a pressure testing valve incorporated within the casing. The pressure testing valve further comprises a sleeve positioned within a housing and transitional from a first to a second position, and from the second to a third position. When the sleeve is in the first and second positions, the sleeve blocks a route of fluid communication via one or more housing ports. When the sleeve is in the third position the sleeve does not block fluid communication. The pressure testing valve is configured such that the sleeve transitions from the first position to the second position when a force in the direction of the second position is applied to the sleeve. When in the second position, a reduction of the force in the direction of the second position to the sleeve causes the sleeve to transition to the third position.

Pressure testing valve and method of using the same

An improved downhole tool apparatus for limiting the extrusion of a sealing elements in downhole tools that use segmented retaining assemblies, retaining shoes or retaining limiters. The apparatus provides for locating the retaining bands for the retaining assemblies in a groove on the inner surface of the retaining assembly so that the bands are protected from breaking prematurely by inadvertently contacting the wellbore, casing within a wellbore, or other object.

Protected retaining bands

A downhole apparatus suitable for downhole application may include a mandrel; a packer element assembly disposed about the mandrel that comprises at least one packer element disposed about the mandrel; and a retaining shoe disposed about the mandrel and adjacent to a first packer element of the packer element assembly. The retaining shoe may be configured such that in an unset position at least a portion of the first packer element covers at least a portion of a retaining shoe distal surface.

Covered retaining shoe configurations for use in a downhole tool

A downhole tool for use in a well. A pumpable plug is used to urge bottom hole assemblies to a desired location in a well. The pumpable plug has a diameter greater than the maximum outer diameter of the casing in which the bottom hole assembly is to be located.

Downhole tool with pumpable section

A downhole tool for use in a well. The tool has a packer assembly and a pumpable plug associated with the packer assembly. The pumpable plug has a diameter greater than the maximum outer diameter of the packer assembly. The pumpable plug may be pumped through a casing having a diameter larger than that for which the packer assembly is designed and will urge the packer assembly through the large diameter casing into a smaller diameter casing for which the packer assembly is designed.

A wellbore servicing system, comprising a plurality of sleeve systems disposed in a wellbore, each sleeve system comprising a seat and a dart configured to selectively seal against the seat to the exclusion of other seats, the seats each comprising an upper seat landing surface and the darts each comprising a dart landing surface, wherein the darts each comprise a dart landing surface that is configured to complement an upper seat landing surface of the seat to which the dart is configured to selectively seal against.

System and method for servicing a wellbore

A bridge plug having a segmented backup shoe, and at least one split cone extrusion limiter, the extrusion limiter comprising a two part conical retainer positioned between packer elements and the segmented backup shoe to block packer element extrusion though spaces between backup shoe segments. In one embodiment, two split cone extrusion limiters are used together and positioned so that each split cone extrusion limiter covers gaps in the other extrusion limiter and together the two split cone extrusion limiters block packer element extrusion though gaps between backup shoe segments regardless of their orientation relative to the segmented backup shoe. In one embodiment, a solid retaining ring is positioned between a split retaining cone extrusion limiter and a packer element and resists extrusion of packer elements into spaces in the split cone extrusion limiter or limiters.

Packer element retaining system

A tool and a method for sealing a casing or a wellbore according to which a device is supported on a mandrel and expands into engagement with the casing or the wellbore. An explosive cutter is also supported on the mandrel and is adapted to explode to cut the mandrel and the device and release the engagement.

Sealing plug and method for removing same from a well

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 hydraulic setting tool for packers capable of mechanically setting the packer and opening a valve in the packer in one trip. The tool comprises an outer sleeve and an inner mandrel coaxially disposed within the outer sleeve and adapted to move axially relative to the outer sleeve. The tool further comprises three locking mechnisms that unlock under different fluid pressure loads. Two of the locking mechanisms lock the inner mandrel to the outer sleeve in a run-in position. Once a sufficient fluid pressure has been reached to unlock both of these locking mechanisms, the inner mandrel moves upward relative to the outer sleeve to set the packer. A spring forces the inner mandrel into a third position relative to the outer sleeve, which is maintained by the third locking mechanism. This third position is used to open the packer valve.

Growing community of inventors

Wilson, OK, United States of America

Donald R Smith