Schlumberger Patente

A computerized method for evaluating a drill cuttings lithology includes acquiring a digital image of drill cuttings and segmenting the acquired image at a rig site to demarcate individual particles in image. Features are extracted from selected ones of the demarcated particles in the segmented image and the demarcated particles are further assigned to at least one group based on the extracted features at the rig site. A rig site user is prompted to input measurement data, a label, or a description of the at least one group. The segmented image, the extracted features, the assigned grouping, and the user input are electronically transferred to a cloud computing resource which performs a lithological classification of selected ones of the demarcated particles based on the extracted features and the user input and generates consolidated summary results of the lithological classification.

Certain aspects of the present disclosure provide a method for removing PFAS contaminants from a PFAS contaminated aqueous stream. The method includes introducing the PFAS contaminated aqueous stream into a reactor with a photocatalyst reagent in the presence of UV radiation and ultrasonic energy to degrade the PFAS contaminants and produce a treated aqueous stream comprising byproducts of the degraded PFAS contaminants.

A system for a permanent magnet synchronous motor (PMSM) includes: a command controller dividing a torque command value by a motor torque constant to generate a reference quadrature component value (CV) of a stator current (I_{q_ref}), an offset controller: receiving and offsetting a fixed rotor angle value (θ_{e_fixed}) by -90° to output an applied rotor angle value (θ_{e_applied}), a torque controller: receiving a reference direct CV of the stator current (I_{d_ref}) combined with a direct CV of stator current (I_d), outputting a direct component of stator voltage (V_ds), receiving the I_{q_ref} combined with a quadrature CV of stator current (I_q), and outputting a quadrature component of stator voltage vector (V_qs), a transfer function generator: receiving the V_ds, V_qs, and θ_{e_applied}, and generating first and second voltage values, and a space vector PWM generator: receiving the first and the second voltage values and generating a PWM waveform for the PMSM.

A spring shoulder kit (114) includes an expanding shoulder (130) and a retaining sleeve (132). The expanding shoulder (130) includes a wedge (146) outwardly radially extending from a radially flexible finger (140). The retaining sleeve (132) is slidably insertable into the expanding shoulder (130) to block inward radial movement of the wedge (146).

A downhole tool for a drillstring that includes a mud motor (310) and a drill bit (304) can include sensor circuitry that acquires data characteristic of operation of the mud motor, wherein the mud motor is disposed on the drillstring between the downhole tool and the drill bit; and a telemetry interface for transmission of one or more of the data and data derived metrics.

A first velocity model having a three-dimensional (3D) grid of voxels containing velocity values is processed with an eikonal solver to generate a reference travel-time model as a second 3D grid of voxels containing respective reference travel-time values. A candidate background model is initialized based on the first velocity model. A candidate travel-time model is generated from the candidate background model. The candidate travel-time model has a third 3D grid of voxels containing respective candidate travel-time values. The candidate background model is updated to minimize a measure of difference between respective candidate travel-time values of the candidate travel-time model and respective reference travel-time values of the reference travel-time model. The updated candidate model serves as a second velocity model of the subsurface region that is kinematically equivalent to the first velocity model.

Systems and methods for direct arrival estimation for marine seismic data are provided. A computer-implemented method for estimating direct-arrival energy in seismic data acquired in a marine environment, the method including: executing, by one or more processors, operations on seismic data that contain up-going and down-going wavefields in which direct-arrival information is not properly or completely recorded, processing the seismic data using a computer-based wavefield-analysis technique to identify water-layer reverberation events within the up-going and down-going wavefields, leveraging, through computer-implemented analysis, stable relationships among water-layer reverberations, computing, by the processors, an estimated direct-arrival signal based on the identified relationships to compensate for missing or improperly recorded direct-arrival information, and producing, using the processors, a direct-arrival estimate configured for use in subsequent seismic-processing operations.

A method for determining a recalibration trigger for a downhole survey sensor includes obtaining historical calibration and recalibration data for a plurality of downhole survey sensors. The historical calibration data is evaluated to determine calibration changes for selected ones of the survey sensors. A probabilistic model is constructed from the determined calibration changes over a predetermined range of temperatures and benchmarked against at least one industry standard to estimate the recalibration trigger.

Methods and systems are provided for detecting and mitigating stall of a downhole motor driven by flow of drilling fluid through the downhole motor, which employ a BHA that includes at least one first downhole sensor and at least one second downhole sensor operably disposed above the downhole motor. The methods and systems generate time-series first data representing measurements of the rotational speed of a collar disposed at the uphole end of the downhole motor or part of the BHA disposed above the downhole motor made by the at least one first downhole sensor over time as well as time-series second data representing measurements of the vibration of the BHA made by the at least one second downhole sensor over time. Stall of the downhole motor can be automatically detected by analysis of the time-series first data and the time-series second data. Upon detecting stall of the downhole motor, at least one action can be initiated to mitigate the stall of the downhole motor.

A high density carrier fluid for use in placing a gravel pack within a wellbore includes a modified starch, a magnesium oxide, and a nano-crystalline-cellulose having a median diameter of about 20 nanometers or less. The carrier fluid includes an aqueous base fluid and dissolved salts. Related methods are also disclosed.

Methods and systems for drilling a wellbore that traverses a subterranean formation employ a computational model that relates input data representing at least one drilling performance parameter (or change therein) at one or more drilling conditions to output data representing at least one petrophysical formation property. Data representing at least one drilling performance parameter (or change therein) at one or more drilling conditions while drilling is determined by sweeping wellbore pressure over a range of pressures and measuring and analyzing wellbore pressures and associated drilling performance parameters, and such data is used as input data to the computational model, which generates output data representing at least one petrophysical formation property associated with the input data. The data output by the model can be added to well log of formation properties, which can be used to set or adjust the direction of drilling.

A method including preparing a surface of a substrate, wherein the surface of the substrate includes a carbonous material, controlling, via a control system, a LIG subsystem to generate a LIG modified area of the substrate, modifying, via an electrochemical subsystem, the LIG modified area of the substrate to generate a sensing area comprising one or more types of nanoparticles, and performing, via a SERS subsystem, detection of a spectral signature of one or more PFAS compounds on the sensing area.

Thermal management systems and methods are provided for conditioning an indoor fluid being delivered to thermal zones of a building. A heat pump system circulates a heat transfer fluid between a first heat exchanger and a second heat exchanger. The first heat exchanger thermally connects the heat transfer fluid with a heat source, and the second heat exchanger is operable to condition the indoor fluid via the heat transfer fluid. A controller communicating with the heat pump system is configured to: receive, for each thermal zone, data indicative of a demand of the thermal zone for the indoor fluid; identify, based on the data, thermal zones satisfying a demand condition; calculate a demand factor of the building based on a number of the identified thermal zones satisfying the demand condition; and adjust an operating parameter of the heat pump system when the demand factor meets or exceeds a threshold value.

A method implements automation of product carbon footprint computations. A process map view is displayed, including multiple process nodes and product nodes. A process view is displayed for a process model associated with one of the process nodes. The process map view is updated with a footprint node that is connected to one or more process nodes. A set of process models, including the selected process model, is processed using footprint data from the footprint node to calculate process emissions. The process map view is updated to display the calculated emissions for the connected process nodes. The process emissions are further processed to determine an overall emission value. A dashboard view is displayed showing the emission value for a product represented by a product node.

A method for improving subsurface images includes receiving data from at least one source and one receiver disposed at a subsurface location. The method may include representing the subsurface location with a dense grid of point scatterers, calculating a wavefield of the source based on the position of the source within the subsurface location, calculating a wavefield of the receiver based on the position of the receiver within the subsurface location and on the grid of point scatterers, and forming an unweighted image of point spread functions (PSFs). The method may also include forming a weighted image of PSFs. The method may also include calculating an image of the weight based on the weighted image of PSFs and the unweighted image of PSFs, and generating a partitioned image of PSFs based on the image of the weight, thereby preventing PSFs from overlapping and improving images of the subsurface location.

An electrical cable includes a central electrical conductor disposed in a center portion of the electrical cable and one or more additional electrical conductors, such that the one or more additional electrical conductors are disposed proximate to the central electrical conductor and form a core of the electrical cable. Additionally, the electrical cable includes one or more fillers disposed between the one or more additional electrical conductors. Further, the electrical cable includes a first layer of armor wires disposed circumferentially around an external surface of the core, such that the first layer of armor wires is partially embedded within an inner carbon fiber reinforced polymer layer, and a second layer of armor wires disposed circumferentially around the first layer of armor wires, such that the second layer of armor wires is partially embedded within an outer carbon fiber reinforced polymer layer.

A method of synthesizing a monolithic structure is provided, which involves casting a gel of nanoparticle material using a mold body. The gel includes the nanoparticle material in reaction media. The mold body is dissolvable in media different from the reaction media at predefined process conditions. Other aspects are described and claimed.

A packed bed unit for chemical processing is described. The packed bed unit includes packing material disposed within the packed bed unit, wherein the packing material includes a plurality of different compositions distributed in the packed bed unit.

An apparatus is provided for use in a chemical process, which includes at least one metal tube or flow channel having at least one surface with at least one organic linker attached thereto. The at least one organic linker has first and second molecular groups, wherein the first molecular group is configured to bind to the at least one surface, and wherein the second molecular group is configured to bind to at least one compound that functions as an adsorbent or catalyst in the chemical process in order to attach the at least one compound to the at least one surface. Methods of constructing an apparatus for use in a chemical process are also described and claimed.

A method can include receiving a target density value for a drilling fluid exiting a sedimentation device; receiving a measured density value for the drilling fluid directed to the sedimentation device, a measured density value for the drilling fluid exiting the sedimentation device, and an incoming flow rate value for the drilling fluid directed to the sedimentation device; and generating control instructions for control of an injection pump to regulate a diluent injection pump rate to dilute the drilling fluid entering the sedimentation device to achieve the target density value.

Systems and methods for enhancing wireline conveyance modeling in wireline conveyance using a physics-informed neural network (PINN) are provided. A method includes: receiving historical job data from at least one past wireline conveyance operation, the historical job data including: static input data, and timeseries input data, processing the historical job data through a neural network (NN) configured to learn the relationships between input features and target variables including: an input layer, a plurality of hidden layers, and an output layer, integrating the neural network with a numerical physics-based wireline conveyance model to form a physics-informed neural network (PINN), training the PINN using the historical job data and estimation results of the physical model to enhance prediction accuracy, utilizing the trained PINN to predict at least one physical parameter for a current wireline conveyance operation, and outputting the predicted at least one physical parameter for use in the wireline conveyance operation.

Systems and methods presented herein provide for cutting in a borehole or casing. A cutting device can include a first arm having a cutting blade, wherein the cutting blade has side cutting teeth and an axis of rotation that is substantially at a right angle with respect to an axis of the tool body. The cutting device can also include a second arm with a bumper. The first and second arms articulate away from the elongate body in different directions to reduce vibrations while cutting. A control device can automate the cut based on hydraulic pressure measurements. Additionally, the cutting device can also be extended or rotated on a rotary index. The cutting device can rotate around a J slot, in an example.

A method for estimating dogleg severity includes rotating the downhole tool in a wellbore. The downhole tool includes a roll stabilized sensor housing deployed in a rotating collar. The collar includes at least first and second magnets deployed thereon. Cross-axial magnetic field measurements are made using a magnetic field sensor deployed in the sensor housing while the collar rotates. A distortion is identified in the magnetic field measurements. The dogleg severity is estimated from the distortion.

A system and method are provided for installing a well for a borehole heat exchanger. The method includes drilling a hole formation to a predetermined depth relative to a ground surface, including operating a bottomhole assembly (BHA) including a drill bit (108) supported at a bottom end of a cable (118) positioned within a flexible tube (104). After drilling the hole formation to a predetermined depth, the BHA is retracted through the flexible tube to remove the BHA from the hole formation while the flexible tube remains in the hole formation.

A method for surveying a wellbore includes rotating a wellbore surveying tool in a wellbore. The wellbore surveying tool includes a plurality of magnetometers, a plurality of accelerometers, and, optionally, a plurality of temperature sensors. Sensor measurements are made while the survey tool rotates in the wellbore. A failed accelerometer or a failed temperature sensor is automatically detected from the accelerometer measurements or the temperature measurements. Corrected sensor measurements are computed for the failed sensor from selected ones of the magnetometer measurements, the accelerometer measurements, and the temperature measurements and used to further compute at least one of a wellbore inclination or a wellbore azimuth.

A method for surveying a wellbore includes rotating a downhole tool having a tilted survey sensor in the wellbore. The tilted survey sensor has a sensory axis that is rotationally offset from a longitudinal axis of the downhole tool and is used to make sensor measurements while rotating the downhole tool in the wellbore. The sensor measurements are fit with a sinusoidal fitting function to obtain first and second fitting parameters. A wellbore survey parameter such as wellbore inclination or wellbore azimuth is computed from the first and second fitting parameters.

An electrochemical reactor, which may be a half-cell of a rechargeable battery, contains a liquid electrolyte which is pumped through the half-cell and has an electrochemical system in which a solid is deposited at an electrode while electric current is flowing. The liquid contains a high molecular weight polymer or a viscoelastic surfactant enabling elastic turbulence to occur and the half-cell is configured to compel through flow to make changes in direction, so that elastic turbulence occurs, enhancing mass transport through the liquid and reducing overpotential at the electrode, which enhances uniformity of deposited solid and inhibits parasitic reactions.

A system includes a bottom hole assembly (BHA), including at least one valve including a bistable actuator coupled to a stem having a valve element, wherein the bistable actuator is configured to move the stem along an axial path of travel to position the valve element in an open position or a closed position relative to a valve seat. The at least one valve also includes a pressure-compensated seal disposed about the stem, wherein the pressure-compensated seal is disposed between an interior fluid chamber and a fluid flow path through the at least one valve.

A regenerative fuel cell has one half-cell which produces gas while charging and consumes the gas during discharge. The electrolyte liquid circulated through that half-cell contains a flexible long chain polymer or a viscoelastic surfactant. The half-cell is configured to compel the flow of electrolyte liquid to make repeated changes in direction and the flow rate is sufficient that elastic turbulence occurs. This dislodges bubbles of produced gas from the electrodes, maintaining more electrode surface available for reaction and enhancing efficiency. The other half-cell may also be in a state of elastic turbulence enhancing mass transport to and from its electrode surface

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