Baker Hughes Corporation

Saudi Arabian Oil Company

Motorola Corporation

Baker Hughes, a Ge Compnay, LLC

Baker Hughes Holdings LLC

Sebastian Csutak

Max Deffenbaugh

Miguel Gonzalez

Huseyin Rahmi Seren

Gregory D Ham

Carl M Edwards

Sunder Ramachandran

Rocco DiFoggio

Katherine Leigh Hull

Younane N Abousleiman

Jose Oliverio Alvarez

Weichang Li

Christopher Powell

Gregory Bernero

Wei E Wu

Robert W Adams

Angelo Sampaolo

Thomas Kruspe

Otto N Fanini

Volker Krueger

Daniel T Georgi

William James Taylor, Jr

Robert E Jones

David J Jacobi

Othon Rego Monteiro

Shannon Lee Eichmann

Yi Liu

Sebastian Jung

Holger Mathiszik

Anuj Gupta

Kent A Byerly

Mohamed Daoud

Alexandr Nikolaevich Vasilevskiy

Kerry L Sanderlin

Tiffany Dawn McAlpin

Burt Wayne Fowler

Felix Wellmann

Huseyin Seren

Embodiments of the invention provide an untethered apparatus for measuring properties along a subterranean well. According to at least one embodiment, the untethered apparatus includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered apparatus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Method and device for obtaining measurements of downhole properties in a subterranean well

An untethered apparatus for measuring properties along a subterranean well includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered apparatus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

Systems, apparatuses, and computer-implemented methods are provided for the sensing and prediction of properties of source rock. Disclosed here is a method of predicting the maturity of a source rock that includes obtaining a plurality of data of a sample source rock from a plurality of data acquisition devices placed in vicinity of the sample source rock and analyzing the received data using a predictive correlation to determine maturity of the sample source rock. The predictive correlation is generated by applying a machine learning model to correlate the plurality of data acquired from a plurality of representative source rocks with a plurality of properties of the plurality of representative source rocks.

Collaborative sensing and prediction of source rock properties

An apparatus for determining properties of an uncharacterized downhole fluid. The apparatus comprises an oscillation driver circuit comprising an amplifier having an output and an input, a feedback loop between the output and input of an amplifier or a logic gate, an electromechanical resonator disposed within the feedback loop such that a the resonator is driven by the oscillation driver circuit, wherein a resonant frequency of the resonator defines an oscillation frequency of the oscillator circuit, and a switch device for causing the oscillator circuit to stop driving the resonator, which thereby enables observation of a decay rate of the oscillation of the electromechanical resonator within the uncharacterized fluid. The electromechanical resonator is enclosed in a conductive layer to protect the resonator against capacitive effects of the downhole fluid.

Method for capacitive cancellation of tuning fork for fluid property measurements

A method of determining a risk of corrosion and scale formation of tubing in a wellbore includes receiving, from a plurality of first sensors positioned at a downhole location of a wellbore, first production stream information and receiving, from a plurality of second sensors positioned at an uphole location, second production stream information. The method also includes performing a material balance to determine a first value representing a difference between a first production steam flow rate at the downhole location and a second production stream flow rate at the uphole location. The method also includes determining a second value representing a critical metal ion concentration of the production stream and, based on a result of comparing the first value with a threshold and based on the second value, determining a third value representing a risk of corrosion and scale formation at the tubing disposed within the wellbore.

Managing corrosion and scale buildup in a wellbore

A method and device are described for making in situ measurements of the density and viscosity of downhole fluids at subterranean wells. An oscillator circuit is deployed in the well comprising an amplifier, a feedback loop, and an electromechanical resonator. The electromechanical resonator is a component in the feedback loop of the oscillator circuit, and has a resonance mode that determines the frequency of the oscillator circuit. The electromechanical resonator is also in contact with the fluid such that the density and viscosity of the fluid influence the resonant frequency and damping of the resonator. The frequency of the oscillator is measured by a microcontroller. In one embodiment, the oscillator circuit periodically stops driving the electromechanical resonator such that the oscillation decays and the rate of decay is also measured by the microcontroller. The density and viscosity of the fluid are determined from the frequency and rate of decay of the oscillation. This measurement technique provides a faster response time to fluid changes than is possible with conventional measurement methods, and the fast response time opens up new applications for downhole viscosity and density measurements, including determining PVT characteristics, phase diagrams, and flow rates.

Method and device for measuring fluid properties using an electromechanical resonator

An untethered apparatus for measuring properties along a subterranean well. According to at least one embodiment, the untethered apparatus includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered apparatus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well.

The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes receiving, an electron spin resonance (ESR) image from an in-situ ESR scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; determining, a spin concentration level of a source rock in the first subterranean location based on the ESR image; and determining, the source rock potential at the first subterranean location based on the determined spin concentration level.

Measuring source rock potential using a quantum electronic scanner

A downhole system includes a quartz enhanced photoacoustic spectrometer (QEPAS) configured to be positioned within a wellbore formed in a subterranean zone of a hydrocarbon formation, a sampling system coupled to the QEPAS, and a computer system connected to the QEPAS. The sampling system is configured to be positioned in the wellbore and obtain a sample of a wellbore fluid at a downhole location in the subterranean zone. The QEPAS is configured to spectroscopically scan the sample and to determine a plurality of quantities of a corresponding plurality of hydrocarbons in the same. The computer system includes one or more processors to perform operations including receiving the plurality of quantities of the plurality of hydrocarbons in the sample and determining a plurality of ratios, where each ratio is a ratio of one of the plurality of hydrocarbons with another of the plurality of hydrocarbons.

Photoacoustic gas detection

The present disclosure describes methods and systems for determining source rock potential in a subterranean region of a hydrocarbon reservoir. One method includes: receiving, a terahertz (THz) scanning image from an in-situ THz scanner that is attached to a wellbore at a first subterranean location, wherein the wellbore extends into the subterranean region of the hydrocarbon reservoir; identifying, components of a source rock in the first subterranean location based on the THz scanning image; and determining, the source rock potential at the first subterranean location based on the identified components of the source rock.

Measuring source rock potential using terahertz analysis

A method of estimating one or both of compaction or subsidence of a subterranean formation with gravity measurements. The free air gradient at surface is measured and compared with gravity measured in a borehole that intersects the formation. At a later point in time, values for gravity are re-measured, differences between the measured values at the initial point in time, and the later point in time are estimated. The differences are used to estimate the compaction or subsidence. A gravimeter can be used for measuring gravity, markers in the formation can be used in conjunction with the gravimeter.

Estimate of subsidence and compaction with borehole gravity measurements

Examples of nano-level evaluation of kerogen-rich reservoir rock are described. A micro-scale beam is formed from kerogen-rich reservoir rock. The beam has reservoir rock and kerogen, which has polymeric properties. A maximum dimension of the micro-scale beam is at most 1000 micrometers. A mechanical experiment that includes a tension test or a compression test is performed on the micro-scale beam. The mechanical experiment is imaged using a scanning electron microscope (SEM). A material parameter of the kerogen in the micro-scale beam is determined based on results of the mechanical experiment and images obtained responsive to the imaging. The material parameter includes a behavior of the kerogen in response to the mechanical experiment. The behavior of the kerogen can be used to determine, among other things, the energy required to break kerogen in a kerogen-rich shale to improve hydraulic fracturing efficiency.

Nano-level evaluation of kerogen-rich reservoir rock

Growing community of inventors

Houston, TX, United States of America

Sebastian Csutak