Baker Hughes, a Ge Compnay, LLC

Baker Hughes Corporation

Baker Hughes Oilfield Operations LLC

Matthew J Krueger

Christopher Ryan Hern

Charles Meador

Daniel C Ewing

Frank J Maenza

Michael A Carmody

Jeffrey Williams

Andy Tom

Michael Ramon

Steve Michael Cortez

Mark E Ramey

Jason P Lacombe

Travis J Ansohn

Clifford Thomas Frazee

Guijun Deng

Sidney K Smith, Jr

Joshua Snitkoff

Wayne Furlan

Thorsten Regener

Bryan Pendleton

Jonathan Mackey Hanson

Sibu Varghese

Joseph E Sheehan

Eric Halfmann

William J Cauley

John Vu

Robert Pena

Deshuttaney Mosley

Mark J Knebel

Mahmoud Marzouk

Nils Neumann

Shannon Martin

Russell Kurtis Fleetwood

Leif Nordenstam

Robert Roland

Mahmoud M Marzouk

Bryan P Pendleton

Charles M Meador

Christopher R Hern

A tool with anti-preset feature including a tool body including a setter, an anti-preset member anchoring the setter to the tool, and a releaser that loses structural integrity through heat or chemical degradation upon receipt of a signal configured to defeat the anti-preset member. A method for setting a liner hanger, including running the liner hanger setting system to a target location in a borehole, sending a signal to the releaser, defeating the releaser, and facilitating relative movement between the liner hanger body and the setter. A borehole system, including a borehole in a subsurface formation, a string in the borehole, and a tool disposed within or as a part of the string.

Liner hanger system and method

A method for assembling a liner system including disposing from an uphole end of the liner a first slip subsystem, disposing from the uphole end of the liner a seal, and disposing from the uphole end of the liner a second slip subsystem.

Method for assembling a liner system

A hanger system including an expandable liner, an expandable first slip subsystem disposed about the liner, an expandable second slip subsystem disposed about the liner, a seal disposed about the liner and between the first slip subsystem and the second slip subsystem, and an expandable lock ring disposed about the liner and against one of the first slip subsystem or the second slip subsystem. A method for lining a borehole including running a liner system into a borehole, landing the liner system in a liner hanger, expanding the first slip subsystem simultaneously with a portion of the liner, expanding the second slip subsystem simultaneously with another portion of the liner, and sealing the liner to the liner hanger between the first slip subsystem and the second slip subsystem with the seal. A borehole system including a borehole in a subsurface formation, a casing in the borehole, and a liner system.

Liner system and method

Yieldable object landing feature including a first object landing region configured to receive and support a first size object, a second object landing region configured to receive and support a second size object, and a stress riser disposed to initiate crack formation in the second object landing region.

Yieldable landing feature

A downhole tool including a tubular member having an outer surface and an inner surface defining a flow bore. An expandable member is arranged on the outer surface. The expandable member is selectively radially outwardly expandable. An activation mechanism is operatively connected to the expandable member. The activation mechanism is operable to radially outwardly expand the expandable member. A control line extends along the outer surface and over the expandable member. A control line guidance system is operable to shift the control line radially outwardly from the outer surface.

Control line guidance system for downhole applications

A tie-back string and a method of coupling the tie-back string to a casing is disclosed. The tie-back string is disposed within the casing. The tie-back string includes an anchor and an actuator section. The actuator section including a sleeve that forms a first chamber and a setting piston that forms a second chamber. A pressure differential is created between the first chamber and the second chamber to move the setting piston to engage the anchor of the tie-back string.

Electric set tieback anchor via pressure cycles

A liner running tool includes a mandrel having a wall including outer surface and an inner surface defining a passage. A projection extends radially outwardly of the outer surface. The projection is formed from a material having a selected melting point and being configured to connect with and support a liner. A thermal activation device is operatively connected to the projection. The thermal activation device is selectively operable to melt the projection and disconnect the liner running tool from the liner.

Disposable liner running tool

A seal system for downhole use in a surrounding tubular includes a seal support including a frusto-conical surface, and a seal member positioned about the seal support. The seal member includes a seal support member including first side having a recess, a second, opposing side, and a seal element coupled to the second, opposing side. The seal element is engageable with the surrounding tubular. An expansion limiter is arranged between the seal support and the seal member. The expansion limiter is positioned in the recess of the seal support member to limit axial movement of the seal member relative to the frusto-conical surface.

System for limiting radial expansion of an expandable seal

A downhole tool including a mandrel, at least one moveable component mounted to the mandrel, and a locking ring mounted to the mandrel. The locking ring includes a plurality of locking ring segments that enable relative movement between the mandrel and the at least one moveable component. A plurality of circumferential spaces is arranged between corresponding ones of the locking ring segments. At least one load bar is arranged in at least one of the plurality of circumferential spaces. The at least one load bar is mechanically connected to the at least one moveable component.

Top set liner hanger and packer with hanger slips above the packer seal

A method of treating a first bore and at least one second bore connected to the first bore in one downhole trip includes guiding a treating tool including a seal assembly defining and a shroud extending about the seal assembly downhole, guiding the seal assembly and the shroud along a diverter positioned near an intersection of the first bore and the at least one second bore into the at least one second bore, shifting the shroud relative to the seal assembly exposing the seal assembly in the at least one second bore, performing a first treatment in the at least one second bore, positioning the seal assembly and the shroud uphole of the diverter, passing the seal assembly through an opening in the diverter having a diverter opening, and performing a second treatment in the first bore.

One trip treating tool for a resource exploration system and method of treating a formation

A mechanically-set packer system for use in a wellbore may include a packer assembly. The packer assembly may include a first ring and a second ring. The packer assembly may also include a packing element positioned between the first ring and the second ring. The packer system may include a mandrel having an interior and an exterior. The packer assembly may be configured to slide onto the exterior of the mandrel. The packer system may further include a line configured to run between the exterior of the mandrel and an interior of the packing element.

Open-hole mechanical packer with external feed through and racked packing system

A mechanically-set packer system for use in a wellbore environment may include a mandrel having an interior and an exterior. The system may further include a packing element positioned along the exterior of the mandrel. The system may also include a line positioned between the exterior of the mandrel and an interior of the packing element.

Open-hole mechanical packer with external feed through run underneath packing system

A system of tubulars includes a non-expandable mandrel having a body including an uphole end, a downhole end, and an outer surface. The non-expandable mandrel includes one or more slip members that are outwardly extendable relative to the outer surface. A seal assembly is arranged at the downhole end of the non-expandable mandrel. The seal assembly is settable after outward expansion of the one or more slip members.

A plug releaser includes, a first tubular with at least one first port through a wall thereof, at least two plugs sealingly engaged with the first tubular defining a first chamber between the first tubular and the at least two plugs. The at least two plugs are rupturable or releasable from the first tubular at selected pressure differentials thereacross, and a second tubular is in operable communication with the first tubular at locations beyond the at least two plugs. The at least one first port provides fluidic communication between the first chamber and an outside of both the first tubular and the second tubular and the at least one first port is sized to prevent pressure differential across the at least two plugs from building to a selected pressure differential needed to rupture or release the plugs in either direction for at least a period of time.

Plug releaser and method of limiting pressure differential across plugs

A telescoping joint is used to space out ends of a string and distribute the string weight between the tie-down locations. The joint can be compressed to reduce its length but has a locking mechanism that prevents extension under tensile loading. The seals in the joint provide a longer service life due to minimization of relative movement in the expansion joint components. The locking mechanism is preferably a ratchet system that uses a body lock ring that is enabled after breaking a shear pin.

Growing community of inventors

Houston, TX, United States of America

Matthew J Krueger