Thru Tubing Solutions, Inc.

Halliburton Energy Services, Inc.

Enventure Global Technology Inc.

Halliburton Company

Eventure Global Technology, LLC

Brock Wayne Watson

Roger Lynn Schultz

Andrew M Ferguson

Gary P Funkhouser

Andy Ferguson

Gregory A Kliewer

David Paul Brisco

Mark S Britton

Jenna N Robertson

Greg Kliewer

Daniel Keith Moeller

Robert G Watson

Brett A Fears

Stanley W Loving

Michael Linley Fripp

Lev Ring

Randy C Tolman

James C Tucker

Arthur Terry Stautzenberger

Ralph Harvey Echols

Kevin J Miller

Kevin Karl Waddell

Harold Otis Treece

T Austin Freeman

Erik Jorgensen

Robert Lance Cook

Henry Eugene Rogers

Colby M Ross

Steven George Streich

Earl Don Webb

Juanita M Cassidy

James E Masino

Mark M Shuster

Grigoriy Grinberg

Donald F Hushbeck

Edwin Arnold Zwald, Jr

Robert K Michael

Scott Costa

Steven Lee Holden

Ronald E Savage

Sam Sun Lloyd

J Tad Bohlen

Steve L Holden

James Frederick Pyecroft

Malcolm Gray

Gary Walters

Joseph S Squyres

Rick L Middaugh

David D Brisco

Paul W Roden

Akin Olufowoshe

William J May, Jr

Alfred H Jones

Russell Wasson

Steve Streich

Robert Phillis

Gary P Funhouser

Roger T Schultz

Greg A Kliewer

David P Brisco

Andrew Ferguson

Ralph H Echols

A method can include directing fluid flow longitudinally through a well tool connected in a tubular string downstream of a longitudinally compressed circulating valve assembly, thereby causing the well tool to operate, and longitudinally elongating the circulating valve assembly while the fluid flow is ceased, and then increasing the fluid flow, thereby causing the fluid flow after the elongating to pass outwardly through a housing of the circulating valve assembly to an external annulus. Another method can include directing a fluid flow through a well tool connected in a tubular string downstream of a circulating valve assembly, thereby causing the well tool to operate, and decreasing then increasing a flow rate of the fluid flow, thereby causing the fluid flow to pass outwardly through a housing assembly of the circulating valve assembly to an external annulus. Circulating valve assemblies are also disclosed.

Circulating valve and associated system and method

A well treatment method can include pumping a treatment fluid through a tubular in a well, deploying plugging devices into the tubular, and blocking flow of the treatment fluid through perforations formed through the tubular. At least one characteristic of the treatment fluid or the plugging devices is varied, thereby in the blocking flow step selectively blocking the flow of the treatment fluid through the perforations in a predetermined sequence. Another well treatment method can include varying at least one characteristic of perforations along an interval, thereby selectively blocking flow of a treatment fluid through the perforations in a predetermined sequence. Another well treatment method can include varying a center flow to side flow (CS) ratio along an interval, thereby selectively blocking flow of a treatment fluid through perforations in a predetermined sequence.

Method of treating an interval via selected perforations/clusters in a subterranean well

A plugging device launcher for use with a subterranean well can include a release mechanism. The release mechanism can include an actuator operative to displace at least one elongated member. The elongated member is engaged with at least one plugging device. A method of releasing plugging devices into a subterranean well can include placing a plugging device launcher in communication with a wellbore of the well, and operating an actuator of the plugging device launcher, thereby displacing at least one elongated member of the plugging device launcher. The displacing step can include disengaging the elongated member from at least one of the plugging devices.

Discrete plugging device launcher

A method can include deploying a diverter plug into a well, the diverter plug comprising a group of particles that are prevented from dispersing, flowing fluid, thereby conveying the diverter plug into engagement with a fluid passageway, the particles conforming to a shape of the fluid passageway as the diverter plug blocks fluid flow through the fluid passageway, and the particles being prevented from dispersing while the diverter plug blocks the fluid flow through the fluid passageway. The diverter plug can include a group of particles disposed within an outer enclosure. The particles in the enclosure can conform to a shape of the fluid passageway as the diverter plug blocks fluid flow through the fluid passageway. In another method, the enclosure can sealingly engage the fluid passageway while the particles remain disposed within the enclosure.

Well operations with grouped particle diverter plug

A jarring tool can include a longitudinally displaceable piston, a first fluid chamber having a volume that decreases in response to displacement of the piston, a flow controller that controls flow of fluid between the first fluid chamber and a second fluid chamber, and a plug seat secured to the piston. A method of applying a jarring force can include applying a pressure differential across a plug in a jarring tool, the plug restricting flow from a first flow passage section to a second flow passage section, then increasing a flow rate of fluid from the first flow passage section. Another jarring tool can include an outer housing with a longitudinal flow passage and seal surfaces at opposite ends of the outer housing, and a flow obstruction, fluid flow through the flow passage being increased in response to application of a pressure differential across the obstruction.

Jarring tool and method of use

A method can include conveying a dispensing tool through a wellbore, the dispensing tool including an enclosure containing plugging devices, and then opening the enclosure by cutting a material of the enclosure, thereby releasing the plugging devices from the enclosure into the wellbore at a downhole location. A dispensing tool can include a container having an enclosure therein, the enclosure including a flexible material that contains the plugging devices, and an end of the enclosure being secured to a member displaceable by an actuator. The enclosure material is cut in response to displacement of the member by the actuator. A plugging device can include at least one body configured to engage an opening in the well and block fluid flow through the opening, and multiple fibers including staple fibers or filaments formed into yarn.

Methods of completing a well and apparatus therefor

A flow conveyed plugging device for use in a well, the device can include a body, and one or more lines extending outwardly from the body, each of the lines having a lateral dimension that is substantially smaller than a size of the body. A method of plugging an opening in a well can include deploying at least one flow conveyed plugging device into the well, the flow conveyed plugging device including a body and, extending outwardly from the body, at least one of the group consisting of: a) one or more fibers and b) one or more lines, the flow conveyed plugging device being conveyed by flow in the well into sealing engagement with the opening. Another flow conveyed plugging device can include a body, and fibers extending outwardly from the body. The flow conveyed plugging device degrades and thereby permits flow through an opening in the well.

Flow control in subterranean wells

A system for use with a subterranean well can include a deployment apparatus configured to deploy one or more plugging devices into a fluid flow. The plugging devices are conveyed into the well by the fluid flow. The deployment apparatus can include multiple queues, different numbers of the plugging devices being contained in respective different ones of the queues. A method of deploying plugging devices can include connecting multiple queues of the plugging devices to a conduit, and deploying the plugging devices from a selected combination of the queues into the conduit. In another system, each of the plugging devices may include a body, and lines or fibers extending outwardly from the body.

Plugging device deployment

A method of treating a subterranean well can include positioning a flow restrictor in a wellbore that penetrates an interval of an earth formation, displacing the flow restrictor along the wellbore away from a surface of the well, preventing longitudinal displacement of the flow restrictor in the wellbore, introducing flow into a first section of the interval from a section of the wellbore between the flow restrictor and the surface, blocking the flow from the wellbore section into the first interval section, permitting longitudinal displacement of the flow restrictor in the wellbore, and displacing the flow restrictor along the wellbore away from the surface of the well, thereby permitting unrestricted flow from the wellbore section into a second section of the interval. The second interval section is farther along the wellbore from the surface than the first interval section.

Fluid flow control during well treatment

A downhole well tool assembly can include a perforator and a selectively openable and closable perforation plug discharge port. A method of perforating and treating multiple formation zones of a well in a single trip of a downhole well tool assembly into the well can include positioning the downhole well tool assembly at a zone, closing a perforation plug discharge port of the downhole well tool assembly, perforating the zone, treating the zone, opening the perforation plug discharge port, deploying perforation plugs into the well via the perforation plug discharge port, plugging perforations in the zone with the perforation plugs, positioning the downhole well tool assembly at a subsequent zone, closing the perforation plug discharge port, perforating the subsequent zone, and treating the subsequent zone.

Multi-zone perforate and treat system and method

A rotary actuator assembly can include a fluid motor with a rotor that displaces with hypocyclic precessional motion within a stator in response to fluid flow through the fluid motor, and a gear reducer section including an input gear that is fixed relative to the rotor and displaces with the hypocyclic precessional motion relative to an output gear. Another rotary actuator assembly can include a fluid motor with a rotor having a central longitudinal axis that rotates about a central longitudinal axis of a stator, and a gear reducer section including an input gear that rotates with the rotor and displaces relative to an output gear, and the input gear having the same central longitudinal axis as the rotor. A well system can include at least two fluid motors, and fluid flow through one fluid motor causes rotation of the other fluid motor in the well.

Rotational speed reduction in downhole tool assemblies

A method can include positioning a flow restrictor in a wellbore that penetrates a formation interval, then displacing the flow restrictor along the wellbore away from the surface, thereby permitting flow into an interval section from a wellbore section between the flow restrictor and the surface, blocking the flow from the wellbore section into the interval section, and displacing the flow restrictor away from the surface, thereby permitting flow from the wellbore section into another interval section farther along the wellbore from the surface. A system can include a flow restrictor that restricts flow through an annulus surrounding the flow restrictor, and plugging devices disposed in a wellbore section positioned between the flow restrictor and a surface of the well. Flow from the wellbore section into a formation interval section is permitted prior to being blocked by the plugging devices.

A method of dislodging a tubular string or well equipment connected to the tubular string can include connecting a dislodging tool in the tubular string, so that a flow passage of the dislodging tool extends through the tubular string, deploying a plug into the dislodging tool, applying a pressure differential across the plug, thereby displacing the plug through a seat of the dislodging tool, and dislodging the tubular string or the component in response to the displacing. A dislodging system can include a dislodging tool connected as part of a tubular string, the dislodging tool including a flow passage and a seat configured to sealingly engage a plug deployed into the tubular string, and at least one of a jarring force, load, impact, shock wave, elastic strain release and pressure pulse being generated in the tubular string in response to displacement of the plug through the seat.

Dislodging tools, systems and methods for use with a subterranean well

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Sadler, TX, United States of America

Brock Wayne Watson