Baker Hughes Corporation

Baker Hughes, a Ge Compnay, LLC

Sunil Kumar

Hendrik John

Anthony Albert DiGiovanni

Othon Rego Monteiro

Danny Eugene Scott

Dan E Scott

Thomas Kruspe

Andreas Peter

Harald Grimmer

Radu Coman

Michael R Wells

Michael Koppe

John Hendrik

Anthony A Digiovanni

Anthony Digiovanni

Othon Monteiro

Dan Scott

A Polycrystalline Diamond Compact (PDC) cutter for a rotary drill bit is provided with an integrated sensor and circuitry for making measurements of a property of a fluid in the borehole and/or an operating condition of the drill bit. A method of manufacture of the PDC cutter and the rotary drill bit is discussed.

PDC sensing element fabrication process and tool

A component of a wellbore tool comprises a plurality of compartments disposed over a body of the component and a coating disposed over at least a portion of a surface of the body. Each compartment comprises a healing agent formulated to form or catalyze the formation of a barrier upon release from the compartment. A matrix material separates the plurality of compartments. Methods of forming wellbore tools include forming a body, forming a plurality of capsules, and forming a coating comprising the capsules over the body. Methods of utilizing a wellbore tool in a subterranean borehole include contacting at least a portion of a body with a fluid comprising a healing agent formulated to a barrier. Coatings for wellbore tools include a fiber comprising a plurality of discrete cells and a matrix material contacting and at least partially surrounding the fiber. Each cell comprises a healing agent.

Coatings for wellbore tools, components having such coatings, and related methods

A method for forming a coating upon a wellbore tool includes forming a pattern of features supported by a body and forming a coating over the pattern of features. Forming the pattern of features includes forming a first feature and forming a second feature spaced from the first feature by a first width at a first elevation and by a second width at a second elevation, the second width being different than the first width, and the first elevation being further from an interior region of the body than the second elevation. Also disclosed is a wellbore tool comprising a coating covering a pattern of features and a method of utilizing a wellbore tool in a subterranean formation, the method including forming a pattern of features, forming a coating over the pattern of features, and disposing the wellbore tool in a borehole.

Methods of coating wellbore tools and components having such coatings

A drilling apparatus includes a drill string to be disposed in a borehole. The drill string includes a tubular, a borehole assembly coupled to the tubular and a drill bit disposed at an end of the borehole assembly. The apparatus includes a strain gauge directly deposited on the drill string.

Sensor on a drilling apparatus

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

Disclosed is an apparatus for monitoring a material configured to perform one or more functions or for actuating the material. One or more electrodes are coupled to the material. An electronic device is coupled to the one or more electrodes and is configured to detect an electrical characteristic of the material to monitor the material or to apply an electrical stimulus to actuate the material.

Smart seals and other elastomer systems for health and pressure monitoring

A drill-bit seismic method where the seismic receivers are located in the BHA. The data detected by these receivers is processed by a downhole processing unit in order to estimate the interval velocity of the seismic wave between the sensors and between the bit and a sensor. Additionally, the processed data might provide the distance to a seismic reflector close to the borehole and the average seismic velocity between the well and this reflector. The processed data can be transmitted to surface location by mud-pulse telemetry. The pilot signal can be also used to process seismic data recorded by receivers located at the earth surface (or close to it).

Drill-bit seismic with downhole sensors

An apparatus for forming a wellbore in a formation may include a bit body and a sensor in the bit body. The sensor may include at least one cutting element and may be configured to generate information relating to a parameter of interest when the drill bit engages a wellbore surface.

At-bit evaluation of formation parameters and drilling parameters

Wellbore tools include a body and a superhydrophobic surface disposed over at least a portion of the body. The superhydrophobic surface includes a patterned surface of a hydrophobic material exhibiting a higher hydrophobicity than an unpatterned surface of the hydrophobic material. A wellbore tool may include a seal, at least one sensor, and at least one flow line, each having at least one superhydrophobic surface. Methods of forming wellbore tools include forming a body, forming a hydrophobic surface over at least a portion of the body, and forming a pattern in a surface of the body, such that the patterned surface exhibits a higher hydrophobicity than an unpatterned surface of the same material.

Wellbore tools having superhydrophobic surfaces, components of such tools, and related methods

The present disclosure is related to an apparatus for taking a sample in a wellbore during drilling operations. The apparatus may include a drill bit configured to form a core and at least one retractable cutter internal to the drill bit for taking the sample from the core. The apparatus may also include equipment for analyzing the sample, extracting fluid from the sample, testing fluid from the sample, encapsulating the sample, and/or tagging the sample. The present disclosure is also related to a method for taking a core sample without interrupting drilling operations. The method includes taking a core sample using a drill bit configured to take a core sample using internal cutters. The method may also include analyzing the sample, extracting fluid from the sample, analyzing fluid from the sample, encapsulating the sample, and/or tagging the sample.

Small core generation and analysis at-bit as LWD tool

The present disclosure relates methods and apparatuses for testing and sampling of underground formations or reservoirs. The apparatus may include at least one extendable element configured to penetrate a formation. The at least one extendable element may include at least one drill bit with a nozzle configured to receive formation fluids. The at least one extendable element may include at least one sensor disposed on the at least one extendable element. The at least one extendable element may also include a source of stimulus for stimulating the formation. The at least one extendable element may be configured to detach and/or attach from/to a bottom hole assembly (BHA). One method may include steps for performing testing on the formation for estimating a parameter of interest of the formation. Another method may include steps for performing testing to estimate a parameter of interest of the formation fluid.

Formation sensing and evaluation drill

An apparatus and method for estimating a parameter of interest in a downhole fluid using fluid testing module. The fluid testing module may include: a substrate comprising at least one microconduit, and a sensor. The sensor may be disposed within the at least one microconduit or external. The apparatus may include a fluid transporter for moving fluid within the microconduit. The method includes estimating a parameter of interest using the fluid testing module.

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Celle, Germany

Sunil Kumar