Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Oilfield Operations LLC

Other

Fraunhofer-Gesellschaft Zur Foerderung Der Angewandten Forschung E.V.

Baker Hughes Holdings LLC

Bj Services, LLC

Baker Hughes Inteq Gmbh

Thomas Kruspe

Martin Blanz

Volker Krueger

Peter Rottengatter

Sebastian Jung

Holger Thern

Gunnar Tackmann

Andreas Peter

Carsten Freyer

Rocco DiFoggio

Songhua Chen

Robert Andrew Slade

Dominik Hoheisel

Hartmut Schrader

Hans Jurgen Faber

Arcady Reiderman

Johannes Witte

Ryan Damont Green

Hans-Juergen Faber

Joachim F Oppelt

Christian Kiesl

Darryl E Trcka

W Allen Gilchrist, Jr

Tobias Kischkat

Brian B Ochoa

Sebastian Tegeler

Eckard Scholz

Mouin Hamdan

Stefan Sroka

Dan Georgi

Ole G Engels

Volker Peters

Sebastian Csutak

Carl M Edwards

Roland Edward Chemali

Rainer Jurgens

Matthias Meister

David R Beard

Ingo Roders

Robert Alan Estes

Harald Grimmer

Wolfgang Schade

Peter Schaefer

Hendrik John

Marcus Oesterberg

Homero C Castillo

Karsten Fuhst

Sushant Dutta

Andreas Hartmann

Sunil Kumar

Holger Tietjen

Michael Koppe

Christian Waltermann

Francis Chad Hanak

Detlef Ragnitz

Michael Köhring

Christian Preiser

Andreas Herbel

Konrad Bethmann

Nikolay Nikolaevich Velker

Martin Folberth

Felix Wellmann

Michael E Gillen

Rochus Rafael Nowosielski

Mike Gillen

Iris Surholt

Rob Hawkes

Hans Rehbock

Thomas Kunkiel

Verónica Vanessa Herrera Baño

Alexander Sergeevich Vershinin

Alexey Vladimirovich Bondarenko

Yuliy Aleksandrovich Dashevskiy

Jonathan Leong

Lennert Rabe

Nils Schneider

Natalja Wendt

Erik Pennewitz

Michael Joseph Mannas

Hans-Jurgen Faber

Christoph Meyer

Gerhard Kurz

Radu Fechete

Holger F Thern

A system herein includes one or more processors to determine asymmetric compensation measurements from at least one receiver antenna pair and at least one transmitter antenna pair on a tool body in an underground formation. The asymmetric compensation measurements are to be used with symmetric compensation measurements from the plurality of antenna pairs. The asymmetric compensation measurements are associated with signals from individual transmitter antennas that are at asymmetric or unequal distances from individual receiver antennas that receive a version of the signals. The individual receiver antennas are part of the at least one receiver antenna pair having symmetrically located receiver antennas with respect to a midpoint of the tool body and the individual transmitter antennas are part of the at least one transmitter antenna pair having symmetrically located transmitter antennas with respect to a midpoint of the tool body.

Downhole logging using symmetric and asymmetric compensated resistivity measurements

Downhole monitoring systems are described. The systems include a downhole string disposed in a borehole, the string having a downhole tool and the borehole has fluid therein. A sacrificial electrical sensor element is arranged in or on the string. The sacrificial electrical sensor element includes magnetic material at least partially exposed to the fluid and at least one coil arranged in magnetic communication with the magnetic material. A controller is configured to provide an electrical current into the coil, measure an electrical property of the coil that is based on the magnetic material in magnetic communication with the coil, and determine a wear state of the downhole tool based on the measured electrical property.

Erosion prediction for downhole tools

A control valve assembly includes a body having a fluid inlet and a fluid outlet. A portion of the body is formed from a first magnetic material. A sleeve is slidingly mounted to the body. At least a portion of the sleeve is formed from a second magnetic material. A magnetic circuit having a gap is defined within the control valve assembly. A solenoid is mounted to the body about at least a portion of the first magnetic material of the body. The solenoid is selectively activated to create a magnetic field across the gap in the magnetic circuit. The magnetic circuit causes the sleeve to slide, narrowing the gap and sliding from the first position to the second position to produce a pressure pulse in the wellbore, wherein the biasing member biases the sleeve back to the first position.

Sleeve control valve for high temperature drilling applications

Methods, systems, devices, and products for acoustic detection in a borehole. Apparatus embodiments comprise an acoustic sensor including a pressure transducer comprising: an interface between a fluid reservoir and a fluid body, the interface including a flexing member attached to an optical medium, the pressure transducer configured to convert an acoustic pressure signal within a nominal borehole pressure incident on the pressure transducer to an alternating strain on the optical medium along an axis of the medium via movement of the flexing member, the acoustic pressure signal propagated via the fluid body; a detector configured to generate acoustic measurement information responsive to received electromagnetic radiation transmitted through the medium along the axis, at least one optical property of the medium being responsive to the alternating strain on the medium; and at least one coupled oscillator displacing a volume of the fluid reservoir responsive to the acoustic pressure signal to modify conversion by the flexing member of signal components of the acoustic pressure signal having a frequency within a predefined frequency range into strain of the optical medium, so that the electromagnetic radiation received by the detector represents a modified acoustic signal.

Downhole fiber optic hydrophone

Wellbore ranging methods and systems for active electromagnetic ranging between a pair of conductive tubulars. Methods may include generating a depth-dependent current on one conductive tubular of the pair and a return current on another and thereby causing an injection current to flow into the earth formation by electrically exciting a first conductive tubular of the pair at a first wellhead and a second of the pair at a second wellhead, wherein the return current on the one results from the injection current on the other and is received from the earth formation; making electromagnetic measurements indicative of at least one electromagnetic field resulting from the depth-dependent current in the earth formation; and estimating a relative position of the first conductive tubular with respect to the second tubular using the electromagnetic measurements.

Active magnetic ranging by wellhead current injection

A down-hole tool includes at least one wall. The at least one wall may include a plurality of joined substantially parallel layers of material, a plurality of pockets defined within the at least one wall, each pocket of the plurality of pockets including a plurality of openings formed in consecutive layers of the plurality of joined substantially parallel layers of material, and a plurality of recesses defined within the at least one wall and between layers of the plurality of joined substantially parallel layers of material, the plurality of recesses defining at least one conduit. The down-hole tool also includes at least one electronic component disposed within a pocket of the plurality of pockets and at least one electrical connection disposed within the at least one conduit.

Down-hole tools comprising layers of materials and related methods

A directional tool and method of surveying a wellbore with the directional tool in a borehole string. A first sensor of the directional tool is disposed in a non-homogeneous ambient magnetic field. A first applied magnetic field is applied to the first sensor. A first measurement is obtained at the first sensor while the first sensor is disposed within the non-homogeneous ambient magnetic field and with the first applied magnetic field applied. A second applied magnetic field is applied to the first sensor. A second measurement is obtained at the first sensor while the first sensor is disposed within the non-homogeneous ambient magnetic field and with the second applied magnetic field applied. The directional tool is calibrated based on the first and second measurement. A downhole survey measurement is obtained with the calibrated directional tool in the wellbore.

Variation H coils calibration method for triaxial magnetometers

A method of estimating a directional parameter of a downhole component includes deploying a borehole string in a borehole, the borehole string including the downhole component, the downhole component being rotatable, the downhole component including a gyroscope device and a magnetometer device. The method also includes collecting gyroscope measurement data from the gyroscope device and magnetic field measurement data from the magnetometer device during rotation of the downhole component, and estimating, by a processor, the directional parameter of the downhole component, where the estimating includes correcting the gyroscope measurement data based on the magnetic field measurement data.

Correction of gyroscopic measurements for directional drilling

A system and method for determining fluid inflow into a wellbore. The system may include a drill string including an earth-boring tool. The drill string may further include a first array of sensors arranged radially about the drill string in a region of the drill string after the earth-boring tool. The drill string may be configured to be inserted into the wellbore and the first array of sensors may be configured to detect an inflow of fluid into the wellbore through a change in an environmental property of the wellbore.

Fluid inflow sensing in a wellbore and related systems and methods

Systems and methods for measuring a parameter of interest in a borehole in an earth formation are provided. The systems include a downhole sensor having a first sensor component with a first temperature and a second sensor component with a second temperature, the downhole sensor disposed on a downhole component. A temperature control system is configured with a thermal control mechanism operatively connected to at least one of the first and second sensor components. The thermal control mechanism is configured to maintain a temperature difference between the first temperature and the second temperature below a pre-determined temperature difference. The downhole sensor is configured to measure the parameter of interest when the temperature difference is below the pre-determined temperature difference.

Device temperature gradient control

A system for acquiring directional information about a geologic formation includes at least one directionally sensitive nuclear magnetic resonance (NMR) assembly disposed at a borehole string including the downhole component. The at least one NMR assembly includes at least one magnet configured to generate a static magnetic field and at least one coil configured to generate an oscillating magnetic field, the at least one NMR assembly configured to perform an NMR measurement of at least one sector of a formation region. The system also includes a processing device configured to receive NMR measurement data from the at least one NMR assembly. The processing device is configured to analyze the NMR measurement data to estimate a parameter of the sector, determine a direction of the downhole component based on the estimated parameter; and steer the downhole component according to the determined direction.

Directional control of downhole component using NMR measurements

Apparatus and methods directed to an assembly associated with a downhole tool, and including: a thermal housing; at least one internal component inside the thermal housing, wherein the at least one internal component comprises at least one thermally sensitive component; and a thermal isolation support connecting the at least one internal component to the tool. The thermal isolation support may comprise an additive manufacturing structural framework connected to the tool. The structural framework may include a plurality of structural members, with a majority of the plurality of structural members substantially non-parallel with a longitudinal axis of the downhole tool.

Thermal barrier for downhole flasked electronics

An apparatus for use in a wellbore includes a downhole tool, a fuel cell, a pressure applicator, and a desiccant. The wellbore has a wellbore fluid at hydrostatic pressure. The downhole tool is conveyed into the wellbore with a conveyance device. The fuel cell is associated with the downhole tool and receives a flow of an oxidant and a flow of hydrogen. The pressure applicator applies at least a portion of the hydrostatic pressure of the wellbore fluid to the fuel cell to increase a pressure applied to the fuel cell. The desiccant receives a fluid byproduct produced by the fuel cell.

Downhole fuel cell with steam adsorption and pressure compensation

A downhole tool including a body having a hydraulic fluid chamber, and a flexible multi-layer barrier impermeable to gas and water mounted at the body separating the hydraulic fluid chamber from fluids external to the body. The flexible multi-layer barrier including a first elastomeric layer, a second elastomeric layer, and a gas impermeable layer arranged between the first elastomeric layer and the second elastomeric layer, the gas impermeable layer being formed from a metal layer.

Water and gas barrier for hydraulic systems

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Wietzendorf, Germany

Thomas Kruspe