Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Oilfield Operations LLC

Baker Hughes Holdings LLC

Nextstream Wired Pipe, LLC

Baker Hughes Ventures & Growth LLC

Bakery Hughes Incorporated

Christian Fulda

Volker Peters

Andreas Peter

Harald Grimmer

Andreas Hartmann

Ingo Roders

Volker Krueger

Stephan Mueller

Oleg N Akimov

Ansgar Baule

Heiko Eggers

Matthias Gorek

Dorothea Marion Fischer

Sven Hollstein

Henning Rahn

Thomas Uhlenberg

Paul Madero

Thorsten Regener

Carsten Hohl

Hans-Martin Maurer

Hans-Juergen Faber

Martin Folberth

Erik Bartscherer

Witali Huber

Eduard Kirchmeier

Gunnar Michaelis

Sven Krueger

Hanno Reckmann

Joerg Lehr

Dmitriy Dashevskiy

Ingo Forstner

Christoph Wesemeier

Tim Mueller

Olaf Gaertner

Thorsten D Roessel

Stephan Dankers

Sven Haberer

Fredrik Jonsbråten

David Selvaag Larsen

Matthias Bücker

Andreas Hördt

Mathias Gorek

A downhole motor, having a body having an outside surface and a longitudinal extent, a first flow passage defined within the body and disposed along the longitudinal extent of the body, and a second flow passage extending from the first flow passage to a channel at the outside surface, wherein a Bernoulli suction force is created at the channel. A method for drilling a borehole, including directing a fluid through a first flow passage defined within a body of a drill and disposed along the longitudinal extent of the body, directing a portion of the fluid from the first flow passage through a second flow passage to a channel at an outside surface to create a Bernoulli suction force at the channel, and drilling a curved section of the borehole by using the Bernoulli suction force at the channel.

Downhole motor with steering capability

A bending stiffness control system in a downhole drilling assembly includes a body configured to be connected to a downhole component of the downhole drilling assembly, the body having a longitudinal axis. The bending stiffness control system also includes a cavity disposed within the body and extending along the longitudinal axis, and a moveable element assembly including one or more moveable elements that are configured to move along the longitudinal axis, the moveable element assembly configured to control a bending stiffness of the body by reacting to a change in an inclination of the body and the longitudinal axis.

Downhole component having a variable bending stiffness

An embodiment of a coupling device is configured to be disposed in a borehole string in a borehole in a subterranean region. The coupling device includes a coupler body having a longitudinal axis, the coupler body including an elongated shaft extending along the longitudinal axis and configured to carry loads through the coupling device, a stiffness control device connected to the elongated shaft, the stiffness control device configured to adjust a bending stiffness of the coupler body, and an actuator configured to cause the stiffness control device to adjust the bending stiffness of the coupler body.

A method for performing automated geosteering includes receiving, by a processing system, formation evaluation data from a bottom hole assembly disposed in a wellbore. The method further includes determining, by the processing system, position data of a formation boundary from the formation evaluation data. The method further includes extrapolating, by the processing system, the position data to generate extrapolated position data of the formation boundary. The method further includes adjusting a trajectory of the wellbore based at least in part on the extrapolated position data of the formation boundary.

Automated geosteering based on a distance to oil-water contact

An apparatus for estimating a first property in a borehole penetrating the earth is described. The apparatus includes a carrier configured to be conveyed through the borehole. The apparatus also includes a first sensor disposed at the carrier and configured to perform a first measurement of the first property, the first sensor having a first direction of sensitivity; a second sensor disposed at the carrier and configured to perform a second measurement of a second property, the second sensor having a second direction of sensitivity; and a processor configured to receive the first and second measurements and to correct the first measurement using the second measurement in order to estimate the first property.

System and method to estimate a property in a borehole

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

An embodiment of a method of performing aspects of a downhole operation includes receiving a measurement value from a first sensor configured to measure a parameter related to the downhole operation, receiving measurement data from a different sensor, the measurement data related to the downhole operation, and performing, by a sensor evaluation module, an evaluation of the first sensor. The evaluation includes determining a condition of the first sensor based on the measurement data from the different sensor, selecting a rule that prescribes a set of one or more measurement values of the parameter that are plausible if the condition is met, and determining whether the measurement value from the first sensor is plausible based on comparing the measurement value to the prescribed set of one or more measurement values.

Evaluation of sensors based on contextual information

A wired pipe system includes a wired pipe segment having a first end and a second end and a first coupler in the first end and a second coupler in the second end. The system also includes a transmission line disposed in the wired pipe segment between the first and second ends. The transmission line includes an inner conductor, an insulating material surrounding the inner conductor, an outer conductor surrounding the insulating material and the inner conductor for at least a portion of a length of the transmission line, the other conductor being formed by deforming around the inner conductor a sheet of material into a substantially tubular member.

Transmission line for wired pipe

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 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 system for performing a wellbore operation while a fluid circulates in a wellbore may include a string, a fluid circulation system, a control device, The string may include at least a first tubular section and a second tubular section. The a fluid circulating system has a first fluid path and a second fluid path, wherein only one of the first fluid path and the second fluid path circulate the fluid into the string at a specified time. The control device selects one of the first or second fluid path through which to convey the fluid into the string, at least one signal generator in hydraulic communication with the circulating fluid, the at least one signal generator configured to impart at least one pressure signal into the circulating fluid, and at least one pressure transducer in pressure communication with the circulating fluid and configured to detect the imparted at least one pressure signal, wherein the at least one signal generator and the at least one pressure transducer form a communication link, the communication link configured to convey information between at least two locations along a flow path of the circulating drilling fluid, irrespective of the fluid path selected by the control device to convey the fluid into the drill string.

Mud pulse telemetry with continuous circulation drilling

A wired pipe system includes a wired pipe segment having a first end and a second end and a first coupler in the first end and a second coupler in the second end. The system also includes a transmission line disposed in the wired pipe segment between the first and second ends. The transmission line includes an inner conductor, an insulating material surrounding the inner conductor, an outer conductor surrounding the insulating material and the inner conductor for at least a portion of a length of the transmission line, the outer conductor being formed by deforming around the inner conductor a sheet of material into a substantially tubular member.

Growing community of inventors

Lower Saxony, Germany

Christian Fulda