Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Deep Vision, Inc.

Baker Hughes Holdings LLC

Harald Grimmer

Volker Krueger

Sven Krueger

Roger W Fincher

Peter S Aronstam

Larry A Watkins

Christian Fulda

Peter Fontana

Carsten Hohl

Volker Peters

Andreas Peter

Heiko Eggers

Gunnar Michaelis

Hendrik John

Thorsten Regener

Erik Bartscherer

Witali Huber

Dorothea Marion Fischer

Thomas Kruspe

Hanno Reckmann

Ingo Roders

Joerg Lehr

Andreas Hohl

Stefan Wessling

Sunil Kumar

Christian Herbig

Detlef Hahn

Cornelis Huiszoon

Michael Koppe

Steffen Toscher

Helmut G Benning

Gerald Heisig

Matthew John Sale

Marcel Brand

Baoyan Li

Joerg Christanseen

Phillip Lawrence Kurkoski

Rune Woie

Frederik Goeing

Marc Aldag

Philip Kurkoski

Matt John Sale

Svan Krueger

Roger Fincher

An apparatus for drilling a directional wellbore is disclosed that in one non-limiting embodiment includes a drive for rotating a drill bit, a deflection device that enables a lower section of the drilling assembly to tilt about a member of the deflection device within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore, and a tilt sensor that provides measurements relating to tilt of the lower section. A controller determines a parameter of interest relating to the tilt for controlling drilling of the directional wellbore.

Drilling apparatus using a self-adjusting deflection device and deflection sensors for drilling directional wells

An apparatus for drilling a directional wellbore is disclosed that in one non-limiting embodiment includes a drive for rotating a drill bit, a deflection device that enables a lower section a drilling assembly to tilt within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore, and a sensor that provides measurements relating a direction of the drilling assembly for drilling the wellbore along a desired direction.

Drilling assembly using a self-adjusting tilt device and sensors for drilling directional wellbores

An apparatus for drilling directional wellbores is disclosed that in one non-limiting embodiment includes a drive for rotating a drill bit, a deflection device that enables a lower section of a drilling assembly to tilt about a member of the deflection device within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore, and at least one seal that isolates at least a surface of the member from outside environment. The at least one seal is lubricated by a sealed hydraulic unit

Drilling apparatus using a sealed self-adjusting deflection device for drilling directional wells

A stator for a downhole motor configured for use in a downhole environment. includes an inner tubular member formed from a first metallic material having an outer surface and a helically lobed inner surface, and an outer tubular member comprising a second metallic material that is different from the first metallic material. The inner tubular member is connected to the outer tubular member by compressive force passing from the outer tubular member through the inner tubular member to a rigid mandrel removably disposed within the inner tubular member. The inner tubular member and the outer tubular member form the stator of the downhole motor.

Method of forming stators for downhole motors

A method of forming a mud motor stator having a passage including a first end defining a first opening, a second end defining a second opening and an intermediate portion extending therebetween includes introducing a liner material into the passage at one of the first end and the second end of the stator, inserting a mandrel having a contoured surface into the passage through one of the first end and the second end of the stator, shifting one of the mandrel and the stator relative to the other of the mandrel and the stator, and flowing the liner material over the contoured surface of the mandrel from the one of the first and second ends toward the other of the first and second ends to form a liner on the inner surface of the passage.

Method for forming a mud motor stator

A method of making a stator includes positioning an inner tubular member having an inner surface within an outer tubular member, installing a rigid mandrel within the inner tubular member, and applying a compressive force to at least one of the inner tubular member and the outer tubular member.

A method for drilling a borehole penetrating an earth formation includes: drilling a first section of the borehole; notching a wall of the borehole in one or more selected locations with a selected type of notch using a notcher for defined local weakening of the formation; performing a local induced break-out test and/or local fracturing operation on an annulus section of the first section of the borehole between the drill string and a wall of the borehole using a test tool comprising a packer to provide formation stress-state data. The one or more locations is based on the formation stress-state data. The method further includes deriving stress-state of the formation and a fracturing parameter of the formation using the formation stress-state data and drilling a second section of the borehole using the derived stress-state and the fracturing parameter.

One run reservoir evaluation and stimulation while drilling

A wellbore apparatus includes a first component having a first element and a second component having a second element. The first component and the second component are connected by a multi-start thread connection and the first element and the second element being operatively connected to one another.

Multi-start thread connection for downhole tools

A method of operating a Moineau system to substantially eliminate vibrations, the method includes rotating a first rotational member, and rotating a second rotational member. Each of the first rotational member and the second rotational member includes a plurality of lobes. A first rotational speed of one of the first rotational member and the second rotational member is selected based on 1) a second rotational speed of the other of the first rotational member and the second rotational member and 2) the number of lobes of one of the first rotational member and the second rotational member to maintain eccentric force of one of the first and second rotational members below a predetermined threshold.

Vibrationless moineau system

An apparatus for use downhole is disclosed that in one embodiment may include a rotor having an outer lobed surface disposed in a stator having an inner lobed surface, wherein the inner lobed-surface or the outer-lobed surface includes a sealing material on a first section thereof and a metallic surface on a second section thereof.

Apparatus and methods utilizing progressive cavity motors and pumps with rotors and/or stators with hybrid liners

Gas from a tight gas formation may be produced using a drain hole having a juncture to a main wellbore and a terminal end at a depth higher than the juncture. The terminal end may be positioned in the tight gas formation.

Upgoing drainholes for reducing liquid-loading in gas wells

An apparatus for measuring strain on a downhole component includes: at least one strain sensitive device disposed proximate to a surface of a component of a drilling assembly or disposed within a material forming the component; and a processor in operable communication with the at least one strain sensitive device, the processor configured to detect changes in the at least one strain sensitive device and detect at least one of erosion, crack formation and crack propagation in the component surface. An apparatus for measuring strain on a downhole component includes: at least one strain gauge deposited on a surface of a drive shaft or disposed within a material forming the drive shaft; and a processor in operable communication with the at least one strain gauge, the processor configured to detect changes in the at least one strain gauge and detect conditions affecting operation of the drive shaft.

Measurement of downhole component stress and surface conditions

An apparatus uses well devices, both downhole and at the surface, to control at least one condition in a wellbore. The downhole equipment includes flow restriction devices that modulate fluid flow along a wellbore annulus, flow bypass devices that selectively bypass fluid flow from wellbore tubular bore to the wellbore annulus, and downhole sensors that generate information relating to a selected parameter of interest. The surface equipment includes a pump that circulates a drilling fluid in the wellbore. Controllers, which may be downhole and/or at the surface, use sensor information to generate advice parameters or signals that may be used to control the flow restriction devices, the flow bypass devices, and/or the fluid circulation pump.

Active equivalent circulating density control with real-time data connection

In one aspect, a drilling apparatus is provided, where the drilling apparatus includes a fluid pump disposed in a main wellbore, a lateral well in fluid communication with the fluid pump and a drilling assembly disposed in the lateral well, wherein the drilling assembly is configured to receive a fluid from the fluid pump to power the drilling assembly and to transport cuttings from the drilling assembly to the main wellbore. The drilling apparatus further includes a sealing mechanism disposed in the main wellbore, the sealing mechanism being configured to direct the cuttings in the fluid downhole of the sealing mechanism.

Lateral well drilling apparatus and method

In an aspect, the disclosure provides an apparatus for use downhole. In one aspect the apparatus includes a rotor with lobes disposed in stator with lobes, wherein at least one of the contours of the rotor lobe and the contour of the stator lobe is asymmetric.

Downhole motors and pumps with asymmetric lobes

Growing community of inventors

Lachendorf, Germany

Harald Grimmer