Baker Hughes, a Ge Compnay, LLC

Baker Hughes Corporation

Baker Hughes Oilfield Operations LLC

Baker Hughes Holdings LLC

Silviu Livescu

Thomas J Watkins

Jeyhun Najafov

John Delorey

D V Satyanarayana Gupta

John Gordon Misselbrook

Richard H Snow

Luis A Castro

Timothy T Ramsey

Geoffrey Presley

Oladele Bello

Bennie J Lindsey

Louis D Garner

Steven Craig

Daniel Moos

Vivekanand Sista

Lubos Vacik

William A H Aitken

Diego A Velez

Pierre-Francois Roux

Trevor A Sturgeon

Bryan Blomquist

Luis Castro

Optic fibers are embedded within the body of a casing section making up a wellbore casing string. The optic fibers are used to detect damage or deformation of the casing string over the lifespan of a wellbore.

Casing-embedded fiber-optics telemetry for real-time well integrity monitoring

Examples described herein provide a computer-implemented method that includes analyzing a first dataset by applying the first dataset to a first model to generate a first result. The method further includes analyzing a second dataset by applying the second dataset to a second model to generate a second result. The method further includes performing validation on the first model and the second model by comparing the first result to the second result. The method further includes, responsive to determining that the first result and the second result match, modifying an operational action of a surface assembly based on at least one of the first result or the second result. The method further includes, responsive to determining that the first result and the second result do not match, updating at least one of the first model or the second model.

Multi-sensor data assimilation and predictive analytics for optimizing well operations

A system for tool monitoring includes one or more tools of an energy industry system, the one or more tools configured to be disposed in one or more boreholes in one or more resource bearing formations, and one or more sensors connected to each tool of the one or more tools, each sensor of the one or more sensors configured to measure at least one parameter related to performance of each tool of the one or more tools. The system also includes a processing device configured to collect measurements of the at least one parameter from each sensor, generate an individual performance history record for each tool, and store the individual performance history record for each tool in a database configured to store individual performance history records for a plurality of tools in one or more energy industry systems.

Downhole tool diagnostics and data analysis

A telemetry system is provided for a coiled tubing-based work string and includes electrical transmission of power and data between sensors in a bottom hole assembly and a controller. One or more optic fibers are used to provide distributed temperature or acoustic sensing along the length of the work string.

Coiled tubing enabled dual telemetry system

A dual telemetric coiled tubing running string for disposing a bottom hole assembly into a wellbore. The dual telemetric coiled tubing running string includes a string of coiled tubing which defines a flowbore along its length, an electrical wire conduit disposed within the flowbore, and an optic fiber disposed within the flowbore.

Dual telemetric coiled tubing system

A telemetry system for a resource exploration and recovery system including a tubular defining a flow bore, and a superconductor wire disposed within the flow bore. A resource exploration and recovery system including a first system, a second system fluidically connected to the first system, and a telemetry system operatively connected to the first system extending into the second system, the telemetry system including a tubular defining a flow bore, and a superconductor wire disposed within the flow bore.

Telemetry system including a super conductor for a resource exploration and recovery system

Systems and methods for conducting production logging for a wellbore are described which incorporate production logging sensors into a bottom hole assembly which is run in on coiled tubing. The production logging system may include a tool for also conducting a secondary operation, such as milling, fishing, perforation or clean out.

Coiled tubing telemetry system and method for production logging and profiling

A wellbore system may include a work string and at least one downhole device connected to a portion of the work string, the downhole device configured to deliver a periodic stream of fluid to a portion of a wellbore. The system may further include at least one sensor configured to detect reflected energy pulses associated with the periodic stream of fluid. The at least one downhole device may be configured to modify a pressure of the periodic stream of fluid in real time based on the reflected energy pulses received in real time.

Pressure pulses for acid stimulation enhancement and optimization

A data monitoring system includes a data monitoring tool incorporated into a work string proximate a bottom hole assembly. The data monitoring tool detects at least one wellbore condition and at least one force experienced by the data monitoring tool.

Real-time tension, compression and torque data monitoring system

Systems and methods for reducing unwanted water and/or gas intrusion into a hydrocarbon production wellbore. The system includes a treatment injection tool for injecting a treatment agent into portions of the formation surrounding the wellbore and a tunneling tool for forming one or more tunnels within the formation. Sensors provide real-time information about wellbore parameters during treatment so that wellbore analysis can be conducted.

Treatment methods for water or gas reduction in hydrocarbon production wells

A system and method of applying periodic energy pulses to a portion of a wellbore, fracture(s), and/or near wellbore to interrogate and/or stimulate at least a portion of the wellbore, fracture(s), and/or near wellbore. The system includes a downhole device that is configured to deliver periodic energy pulses to a portion of the wellbore. The downhole device may deliver various energy pulses such as pressure waves, seismic waves, and/or acoustic waves. Sensors may determine properties of a portion of the wellbore and/or fracture based on energy pulses detected within the wellbore. The sensors may be connected to the downhole tool, may be positioned within the wellbore, and/or may be positioned at the surface. The magnitude and/or frequency of the periodic energy pulses may be varied to change the stimulation and/or interrogation of the wellbore.

System and method for using pressure pulses for fracture stimulation performance enhancement and evaluation

Electrically-operated downhole tools are run into a wellbore on a coiled tubing string which includes tube-wire that is capable of carrying power and data along its length. During operation, a downhole tool is provided power from surface using the tube-wire. Downhole data is provided to the surface via tube-wire.

Systems and methods for operating electrically-actuated coiled tubing tools and sensors

Dual-walled coiled tubing assemblies are used to dispose a flow actuated pump into a wellbore. Dual-walled coiled tubing assemblies include an inner coiled tubing string and an outer coiled tubing string.

Dual-walled coiled tubing with downhole flow actuated pump

A method of planning and/or performing an energy industry operation includes estimating variable coefficient of friction (CoF) functions defining the variation of a CoF as a function of a downhole condition dependent on a selected operational parameter of an energy industry operation, the operation including deploying a downhole component configured to perform the operation, each variable CoF function associated with a different value of the selected operational parameter. The method also includes defining a plurality of operational parameters related to the energy industry operation, including choosing a value of the selected operational parameter, and generating a mathematical model of the operation, the mathematical model describing frictional forces on the carrier based on the plurality of operational parameters, the chosen value of the selected operational parameter and the downhole condition, where generating the model includes calculating the CoF based on the variable CoF function associated with the chosen value.

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Calgary, Canada

Silviu Livescu