A compensation system may comprise an actuator sealed in a chamber. The chamber may comprise an actuator rod and a first bellow, wherein expansion of the first bellow is configured to extend the first bellow into a first cavity in the chamber, which moves the actuator rod towards the first cavity. The chamber may comprise a second bellow, wherein expansion of the second bellow is configured to extend the second bellow into a second cavity in the chamber. The first cavity is configured to be filled with dielectric fluid, the dielectric fluid moving between the first cavity and the second bellow based on a displacement caused by a movement of the actuator rod.
JAPAN ORGANIZATION FOR METALS AND ENERGY SECURITY (Japan)
Inventor
Du, Weijia
Kanno, Takayuki
Dollfus, Hadrien
Amour, Myriam
Abe, Shungo
Abstract
A method can include receiving real-time downhole time series sensor data during production of fluid from a well in fluid communication with a formation reservoir; transforming the real-time downhole time series sensor data to values for a set of predefined model features; detecting a downhole sand event using the values as input to a trained neural network model; and issuing a signal responsive to detection of the downhole sand event.
A device includes a memory configured to store first executable code and a processor coupled to the memory. The processor is configured to calculate performance indicators for a sucker rod pump (SRP) based on performance data of the SRP, determine an operational frequency corresponding to operation of the SRP based on one performance indicator selected from the performance indicators, and initiate transmission of a control signal corresponding to the operational frequency to alter operation of the SRP to correspond to the operational frequency.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/009 - Monitoring of walking-beam pump systems
F04B 47/02 - Pumps or pumping installations specially adapted for raising fluids from great depths, e.g. well pumps the driving mechanisms being situated at ground level
4.
ARTIFICIAL INTELLIGENCE (AI)-POWERED AUTOMATION OF FEASIBILITY MODELING FOR GEOPHYSICAL MONITORING TOOLS
Certain aspects of the disclosure provide a method of feasibility modeling for a plurality of geophysical monitoring tools. The method generally includes processing, using a flow simulation model configured to simulate carbon dioxide flow at a carbon capture and storage (CCS) site, model input parameters associated with the CCS site to generate flow simulation output data; extracting the flow simulation output data; processing the flow simulation output data to simulate a use of geophysical monitoring tools at the CCS site; for each geophysical monitoring tool: simulating a monitoring response; and determining a uncertainty level associated with the generated monitoring response; determining, using a Bayesian framework, a feasibility of implementing one or more of the plurality of geophysical monitoring tools at the CCS site based on the monitoring response and the uncertainty level associated with each of the geophysical monitoring tools and thereby generate a feasibility score for each tool.
A method including receiving, from a user device operated by a user, a request to access a pool of virtual machines. The virtual machines include a first subset of virtual machines and a second subset of virtual machines. The first subset of virtual machines are at a first provisioning level. The second subset of virtual machines includes a second provisioning level that is less than the first provisioning level. The request specifies a provisioning level request. The method also includes receiving a user profile associated with the user. The method also includes assigning, to the user, a selected virtual machine. The selected virtual machine is selected from among the first subset of virtual machines and the second subset of virtual machines based on the user profile and further based on the provisioning level request. The method also includes providing, to the user device, access to the selected virtual machine.
A method of operating a downhole motor on a downhole tool includes generating an electrical energy output with the downhole motor. The electrical energy output flows to an electronics system of the downhole tool. The method further includes applying an electrical energy input to the downhole motor with the electronics system. The method further includes reducing the electrical energy output based on the applied electrical energy input in order to maintain the electrical energy output below an operational threshold of the electronics system.
Disclosed are a facility (100) and a method for providing process steam. The facility (100) comprises a first stage (6) for recovering waste heat in order to increase the temperature of a first heat-transfer fluid that is used to superheat an outlet fluid using a superheating device (8), and a second stage (7) for recovering waste heat in order to increase the temperature of a second heat-transfer fluid that is used to increase the temperature of the first heat-transfer fluid and/or of the outlet fluid.
F01K 3/14 - Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having both steam accumulator and heater, e.g. superheating accumulator
F01K 3/18 - Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters
F22B 1/02 - Methods of steam generation characterised by form of heating method by exploitation of the heat content of hot heat carriers
8.
SYSTEM AND METHOD FOR PERFORMING DRILLING TRAJECTORY PLANNING
A method of operating a downhole system includes receiving trajectory data including a trajectory for steering a downhole tool toward a downhole target. The method includes identifying downhole tool data for the downhole tool. The method includes, based on the trajectory data and the downhole tool data, predicting one or more engineering metrics including one or more downhole tool metrics associated with an operation of the downhole tool in accordance with the trajectory and one or more completion metrics associated with a completion of the borehole at the downhole target. The method includes determining a coherency for the trajectory including determining whether the engineering metrics are within one or more predetermined thresholds. The method includes generating a report of at least some of the engineering metrics including a value of each engineering metric and an indication of whether the value is within the predetermined thresholds.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
Embodiments presented provide for a method for using down hole fluid measurements for hydrocarbon recovery operation. In embodiments, the down hole fluid measurements are used to determine reservoir features to aid in calculations for the reservoir. Downhole fluid measurements may also be used to check the accuracy of a downhole geological architecture and fluid charge parameters, thereby providing a check on geological conditions.
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
Embodiments presented provide for a method for performing waveform processing. In one embodiment, a synthetic dictionary is created and then, using a machine learning process, data is processed to produce a result.
22 into a solvent to a regenerator of a solvent carbon capture system or process. Other heating sources within the carbon capture system may also be integrated to transfer heat to the regenerator.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A porous structural thermoset media is described herein. A method includes dispensing particles of a removable material into a mold, dispensing a structural thermoset material into the mold, curing the structural thermoset material having the particles of the removable material disposed therein to generate a cured structural thermoset material having the particles of the removable material disposed therein, and removing the particles of the removable material from the cured structural thermoset material to generate a porous structural thermoset.
Methods and systems are provided for monitoring operational characteristics of a drilling system that includes a bottom hole assembly having a drill collar operably coupled to a drill bit. A device having an elongate beam and at least one pair of sensors is rigidly secured to a part of the bottom hole assembly to measure strain in the part of the bottom hole assembly. The measurement of strain can be used to derive a measurement of at least one operational parameter of the drilling system, such as dog leg severity of a wellbore, torque on bit, and/or weight on bit.
E21B 47/007 - Measuring stresses in a pipe string or casing
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 44/04 - Automatic control of the tool feed in response to the torque of the drive
14.
SYSTEMS FOR MEASURING A MICROORGANISM CONCENTRATION AND APPLYING A BIOCIDE, AND RELATED METHODS
A system for measuring a microorganism concentration and applying a biocide includes an injection pump in fluid communication with at least one biocide tank and a fluid conduit in fluid communication with a wellbore, microorganism sensor in fluid communication with the fluid conduit and configured to determine a microorganism concentration of fluid in the fluid conduit, and a biocide controller in operable communication with the injection pump and the microorganism sensor. The biocide controller is configured to determine a biocide dosage to apply to the fluid based on the microorganism concentration, and control an operation of the injection pump to apply the biocide dosage to the fluid. Related methods and biocide application systems are also disclosed.
C12Q 1/04 - Determining presence or kind of microorganismUse of selective media for testing antibiotics or bacteriocidesCompositions containing a chemical indicator therefor
G01N 33/48 - Biological material, e.g. blood, urineHaemocytometers
15.
METHODS FOR CONFIDENCE ASSESSMENT WITH FEATURE IMPORTANCE IN DATA DRIVEN ALGORITHMS
Embodiments presented provide for a method for establishing a confidence assessment for data. Data may be segregated by features importance during the confidence assessment, allowing evaluators the ability to determine the quality of data being processed by the method. The method may comprise performing a principal compoenent analysis on k model original features to obtain k principal components representing uncorrelated input data distributions, wherein k is an integer. The method may also comprise computing feature importance weights for each of the k principal component inputs. The method may also comprise identifying any new sample data in-distribution to weighted probabilities compared to assigned cut-offs.
Systems and techniques for establishing tool location in a well and conveyance line characteristics of a conveyance line accommodating the tool. The systems and techniques are directed at a closed loop manner of acquiring well location information. Thus, multiple pass detections of a well feature may be utilized to map, update and/or provide well location information in addition to conveyance line characteristic information in real-time. This may occur in absence of prior stored well mapping information or with supplemental information thereof.
E21B 17/04 - CouplingsJoints between rod and bit, or between rod and rod
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
Systems and methods for maintaining wellsite equipment are presented herein. For example, an integrated digital factory and maintenance system is configured to receive data relating to maintenance tasks for wellsite equipment at a maintenance shop in substantially real-time during performance of the maintenance tasks; to calculate a plurality of yield metrics, each yield metric of the plurality of yield metrics corresponding to respective maintenance stages of the maintenance tasks in substantially real-time during performance of the maintenance tasks; and to provide the plurality of yield metrics via a graphical user interface displayable via a display device. In addition, the integrated digital factory and maintenance system is configured to calculate a predicted turnaround time for the maintenance tasks based on the plurality of yield metrics; and to provide the predicted turnaround time via the graphical user interface.
A fluid testing system includes an enclosure, a fluid container within the enclosure, and a passageway formed in a wall of the fluid container. The fluid testing system also includes a suction pump coupled to the passageway and configured to pump a sample fluid through the passageway to provide a positive level for the sample fluid in an interior chamber of the fluid container.
A progressive cavity pump system may comprise a progressive cavity pump (PCP) configured to be deployed in a wellbore, an electric motor, wherein the PCP is configured to rotate at the same speed as the electric motor, and a first portion of the pumping system is configured to be replaced, via a tensile element, without replacing a second portion of the pumping system. The first portion may comprise the PCP and the second portion may comprise the motor.
Systems and methods presented herein facilitate well operations, and generally relate to wirelessly configuring bottom hole assemblies (BHAs) for use in such well operations. For example, certain embodiments of the present disclosure include a method that includes wirelessly communicatively coupling at least one user computing device to a wireless access point of a wireless access module of a BHA. The method also includes wirelessly receiving one or more command signals from the at least one user computing device via the wireless access point of the wireless access module of the BHA. The method further includes adjusting one more operating settings or procedures of one or more downhole tool components of the BHA based at least in part on the one or more command signals.
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 47/26 - Storing data down-hole, e.g. in a memory or on a record carrier
21.
METHOD AND APPARATUS TO MEASURE PRESSURIZED DENSITY IN A SAMPLING LOOP
Methods and apparatus for measuring pressure density of a fluid are described herein. A system herein includes a fluid pathway; a pressure sensor coupled to the fluid pathway; a density sensor coupled to the fluid pathway; and a volume reduction device coupled to the fluid pathway. A method herein includes circulating a fluid through a fluid pathway; closing a first valve in the fluid pathway; closing a second valve in the fluid pathway; using a volume reduction device located in the fluid pathway between the first valve and the second valve to increase pressure of the fluid; measuring pressure of the fluid in the fluid pathway between the volume reduction device and one of the first valve and the second valve; and measuring a density of the fluid in the fluid pathway between the volume reduction device and one of the first valve and the second valve.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
G01N 9/26 - Investigating density or specific gravity of materialsAnalysing materials by determining density or specific gravity by measuring pressure differences
22.
SYSTEMS AND METHODS FOR MANAGING DRILLING FLUID HEALTH
A fluid health manager may measure fluid health parameters related to bit balling health. A fluid health manager may apply a bit balling model to each of the fluid health parameters to generate a bit balling health rating of the AF, the bit balling model including a parameter weight for the each of the fluid health parameters. A fluid health manager may based on the bit balling health rating, preparing a drilling fluid recommendation to maintain or improve the bit balling health.
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
23.
SYSTEMS AND METHODS FOR MANAGING DRILLING FLUID HEALTH
A fluid health monitoring system may measure fluid health parameters related to NAF emulsion stability. A fluid health monitoring system may apply a stability model to each of the fluid health parameters to generate an emulsion stability rating of the NAF, the stability model including a parameter weight for the each of the fluid health parameters. A fluid health monitoring system may based on the emulsion stability rating, preparing a drilling fluid recommendation to maintain or improve the NAF emulsion stability.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
24.
SYSTEMS AND METHODS FOR MANAGING DRILLING FLUID HEALTH
A fluid health manager may measure fluid health parameters related to sag health of the NAF. A fluid health manager may apply a sag health model to each of the fluid health parameters to generate a sag health rating of the NAF, the sag health model including a parameter weight for the each of the fluid health parameters. A fluid health manager may based on the sag health rating, preparing a drilling fluid recommendation to maintain or improve the sag health.
Techniques and systems for reservoir characterization. One embodiment includes receiving first raw data corresponding to at least one attribute of a well, applying a pre-processing operation to correct at least one error in the first raw data to generate prepared data, transmitting the prepared data to a machine learning system; training the machine learning system into a trained machine learning system using the prepared data, and generating a final model via the trained machine learning system, wherein the final model operates to generate a characterization of a reservoir in a subsurface region of Earth when second raw data is input to the final model.
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
Embodiments presented provide for a jarring device. The jarring device is used in downhole environments during hydrocarbon recovery operations. Embodiments also provide a method for safe use of a jarring device to enable freeing stuck components without damaging wireline equipment.
A cutting element may include a substrate having a base. A cutting element may include an ultrahard layer bonded to the substrate, the ultrahard layer formed from an ultrahard material, the ultrahard layer including: a side surface adjacent to the base, the side surface including a plurality of cutting surfaces; and an upper surface extending into the ultrahard layer.
A steering system may include a steering unit having a plurality of steering pads and a steering connection. A steering system may include a bit having a gauge diameter and a bit connection, the bit connecting to the steering unit at the bit connection and the steering connection, the bit including a plurality of gauge cutting elements located between the bit connection and the plurality of steering pads.
A steering unit may include a housing. A steering unit may include a plurality of actuator supports arranged circumferentially around the housing. A steering unit may include an actuator pad extending through the housing. A steering unit may include a cutting element connected to the housing between two of the plurality of actuator supports.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
A method includes placing, via a bailer, a slurry into a wellbore to deposit a slurry downhole. The slurry includes a solids mixture and a fluid. The method also includes terminating placement of the slurry for a period of time. A viscous pill inhibits settling of the solids mixture, and the slurry displaces the viscous pill in contact with a surface of a screen.
Systems and methods presented herein generally relate to a formation testing platform for quantifying and monitoring deep transient testing (DTT) surface gas rates formation testing data collected by a downhole well tool, which may be adjusted based on surface gas rates directly measured by surface equipment. For example, a method includes flowing one or more fluids from a subterranean formation to flow through a downhole well tool disposed in a wellbore of a well during a deep transient testing (DTT) operation performed by the downhole well tool. The method also includes measuring data related to one or more properties of the one or more fluids using one or more downhole fluid analysis sensors disposed within the downhole well tool, and predicting, via a control system, a first predicted DTT surface gas rate based on the data measured related to the one or more properties of the one or more fluids.
A device for directional drilling includes a body, an actuatable steering pad, an actuator, and a cutting element. The body has a rotational axis. The actuator moves the actuatable steering pad radially outward from the body between an open position and a closed position, and the actuatable steering pad has a contact surface. The cutting element is positioned on the actuatable steering pad with a radially outermost portion of the cutting element radially outward of a radially outermost portion of the contact surface in the closed position and radially inward of the radially outermost portion of the contact surface in the open position.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
A device may include a housing, wherein the housing has a longitudinal axis. A device may include a magnet rotationally fixed to the housing. A device may include a rotational mass supported in the housing and rotatable relative to the housing around a rotational axis with a magnetic field of the magnet penetrating the rotational mass, the rotational mass including an electrically conductive material that produces an eddy current when translated relative to the magnetic field.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
A magnetic parking brake for use in a downhole telemetry tool includes first and second magnets disposed, or spring biased into magnetic engagement with one another. An electromagnetic and/or mechanical mechanism is configured to reduce the magnetic engagement and thereby release the brake.
E21B 41/00 - Equipment or details not covered by groups
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
F16D 63/00 - Brakes not otherwise provided forBrakes combining more than one of the types of groups
F16D 121/20 - Electric or magnetic using electromagnets
This disclosure is directed to drilling tools and, more specifically, drilling bits. One such bit includes a bit body comprising a first gauge pad and a second gauge pad. The bit further includes a first blade comprising a leading portion and a trailing portion, wherein the leading portion is disposed on the first gauge pad with a negative helix angle and the trailing portion is disposed on the second gauge pad with a positive helix angle.
The present disclosure describes a method may include receiving input data comprising geological data, an indication of a set of components to be placed in a layout for the site, and an emission cost estimate for each of the set of components. The method may also include defining uncertainty parameters and generating a plurality of planning scenarios to implement based on the components and uncertainty parameters. Additionally, the method may include determining facility placements, well trajectories, pipeline placements, and a net present value for each of the planning scenarios. Further, the method may include calculating a tax credit for each of the planning scenarios, ranking each of the planning scenarios based on a respective net present value and a respective tax credit to generate a ranked list of the plurality of planning scenarios, and generating a visualization comprising the ranked list of the planning scenarios.
37.
METHOD OF CUSTOMER SENTIMENT ANALYSIS USING LOGS AND FEEDBACK
A method implements customer sentiment analysis using logs and feedback. Log data is received. The log data is processed with a text generation model to generate synthesized text. The synthesized text is processed with a sentiment prediction model to generate a sentiment prediction. The sentiment prediction model is trained with a training label received responsive to a similarity score of a training vector meeting a similarity threshold. The sentiment prediction is presented.
G06F 18/2135 - Feature extraction, e.g. by transforming the feature spaceSummarisationMappings, e.g. subspace methods based on approximation criteria, e.g. principal component analysis
G06F 18/241 - Classification techniques relating to the classification model, e.g. parametric or non-parametric approaches
G06Q 30/02 - MarketingPrice estimation or determinationFundraising
The present disclosure introduces systems and related methods. Each system includes a first water electrolysis subsystem and a second water electrolysis subsystem. The first water electrolysis subsystem electrolyzes water to produce hydrogen and waste thermal energy. The second water electrolysis subsystem electrolyzes water to produce hydrogen utilizing the waste thermal energy produced by the first water electrolysis subsystem.
C25B 9/23 - Cells comprising dimensionally-stable non-movable electrodesAssemblies of constructional parts thereof with diaphragms comprising ion-exchange membranes in or on which electrode material is embedded
C25B 15/08 - Supplying or removing reactants or electrolytesRegeneration of electrolytes
An apparatus for a rotating packed bed reactor (RPB) that may be used to increase the mass-transfer rate between materials, such as a gas and a liquid, through the RPB. The rotor of the RPB may be rotatably driven within a housing at least in part by the direction of a gas in a tangential direction relative to an outer circumferential surface of the rotor. An RPB may include a housing having a gas inlet, a liquid inlet, a gas outlet, and a liquid outlet. The rotor includes a permeable packing configured to facilitate contact between the liquid and the gas passing through the permeable packing while the rotor rotates with respect to the housing. The gas inlet is configured to direct the gas tangentially with respect to the outer circumferential surface of the rotor to thereby cause the rotor to rotate with respect to the housing.
B01J 19/18 - Stationary reactors having moving elements inside
B01J 19/26 - Nozzle-type reactors, i.e. the distribution of the initial reactants within the reactor is effected by their introduction or injection through nozzles
B01J 19/32 - Packing elements in the form of grids or built-up elements for forming a unit or module inside the apparatus for mass or heat transfer
B01J 19/00 - Chemical, physical or physico-chemical processes in generalTheir relevant apparatus
A method can include determining carbon dioxide acoustic properties for at least supercritical carbon dioxide using thermodynamics that relate isothermal compressibility and adiabatic compressibility; determining fluid-saturated rock acoustic properties using the carbon dioxide acoustic properties; and performing a seismic workflow using the fluid-saturated rock acoustic properties.
A wellhead includes a wellhead housing, a hanger configured to support a casing, and multiple passages formed in or along the wellhead housing, through the hanger, external to the wellhead housing, or any combination thereof. The wellhead also includes at least one movable component configured to move relative to the multiple passages to selectively enable a flow of fluid via the multiple passages from an annular space defined between the wellhead housing and the hanger below the hanger to a portion of a bore within the wellhead housing above the hanger.
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
42.
SYSTEMS AND METHODS FOR AUTOMATED COILED TUBING DRILLING OPERATIONS
Systems and methods presented herein facilitate automation of coiled tubing drilling (CTD) operations. For example, a computer-implemented method includes performing a drilling operation via a CTD system; detecting data relating to one or more operating parameters of the drilling operation via one or more sensors of the CTD system during the drilling operation; and automatically adjusting at least one adjustable operating parameter of the drilling operation based on the detected data during the drilling operation.
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
An apparatus for a rotating packed bed reactor (RPB) that may be used to increase the mass-transfer rate between materials, such as a gas and a liquid, through the RPB. The RPB includes a housing, a motor, and a rotor disposed within the housing and operatively connected with the motor. The rotor includes a permeable packing configured to facilitate contact between a liquid and a gas passing through the permeable packing. The rotor includes a heat sink in contact with the permeable packing and configured to transfer heat away from the permeable packing. The heat sink includes a heat rate transfer gradient in a radially inward direction between an outer circumferential surface of the permeable packing and a central axis of the permeable packing.
Systems and methods presented herein facilitate coiled tubing operations, and generally relate to reduction of shock and vibrations to portions of the coiled tubing string. A device includes a first end configured to be disposed downstream of a bottom hole assembly of a coiled tubing drilling string; a second end configured to be disposed downstream of the first end and upstream of a drive of the coiled tubing drilling string; and a moveable valve configured to move from a first position to a second position to divert at least a portion of drilling fluid flow away from the drive when the drilling fluid flow is greater than a preset flow value or a weight on bit is less than a preset weight value and thereby reduce a rotation rate of the drive.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
45.
ITERATIVE ML POWERED HORIZON INTERPRETATION WORKFLOW
Methods and systems for analyzing seismic data to generate multidimensional reports are disclosed. The methods include receiving, by a data engine, seismic data captured at a resource site. The data engine may constrain a machine learning (ML) engine configured for analyzing the captured seismic data. According to one embodiment, the ML engine may be constrained using boundary condition data associated with one or more subsurface geo-properties comprised in, or associated with the seismic data. For example, the boundary condition data may indicate one or more limit data, threshold data, or some other statistical parameter used to impose bounds on the analysis executed by the ML engine. The seismic data may then be analyzed based on the constrained ML engine to generate a multidimensional report. According to one embodiment, the multidimensional report comprises 2-dimensional image data and/or 3-dimensional image data associated with a subsurface of the resource site.
A wellhead system includes a wellhead housing and a hanger configured to support a casing within the wellhead housing. The hanger includes one or more passages formed through the hanger. The wellhead system also includes a seal assembly configured to move relative to the hanger to selectively enable a flow of fluid across the hanger via the one or more passages. The hanger, the seal assembly, and a lock ring may be run together into the wellhead housing.
E21B 33/04 - Casing headsSuspending casings or tubings in well heads
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
47.
LOCAL POWER GENERATION FOR GAS TO LIQUID CONVERSION AND FLARE REDUCTION SYSTEMS AND METHODS
A system for local power generation to power equipment at a well site which may include a gas line configured to receive a gas flow from a well. The system may also include a turbine comprising an inlet and an outlet and configured to receive the gas flow from the gas line at the inlet and generate power based on a pressure differential between the inlet and the outlet.
Systems and methods presented herein include an assembly of tools that can be arranged in a wellbore in such a way that allows a combination of formation testing (e.g., with a modular formation dynamics testing tool, a wireline formation testing tool, and so forth) and drill stem testing (DST). The assembly of tools enables performance of both types of activities potentially in a single run in the hole, and facilitate full control of the reservoir and formation fluids or, in case of injection, of injected fluids inside the tubing or drill pipe. In addition, the assembly of tools allows for multiple set points to perform zonal evaluations with the formation testing tools, and facilitate performance of full scale flow tests with the DST string.
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 43/27 - Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
E21B 47/10 - Locating fluid leaks, intrusions or movements
Methods, systems, and computing systems for operating an electrolyzer include obtaining a ratio of diffusivity in a material at a reference temperature, simulating operation of the electrolyzer in the material at a plurality of current density values at an operating temperature that is different from the reference temperature based at least in part on the ratio of diffusivity, and displaying a result comprising data representing the operation of the electrolyzer using a computer monitor.
Systems and methods presented herein facilitate coiled tubing operations, and generally relate to conveying, via coiled tubing, a downhole well tool into a wellbore extending through a hydrocarbon-bearing reservoir; and performing a plurality of downhole well operations (production operations, perforation operations, testing operations, clean out operations, and so forth) using the downhole well tool. In general, the plurality of downhole well operations may be performed using the downhole well tool while maintaining full well control and without removing the downhole well tool from the wellbore.
Systems, compositions, apparatus, and methods for hydraulically fracturing a subterranean formation traversed by a wellbore including mixing a gelling agent and water to form a base fluid, adding a gas and a proppant to the base fluid to form a foam fluid, alternating injecting into the formation the base fluid and the foam fluid, repeating the alternating injecting, forming regions of higher proppant concentration, and forming channels adjacent to the regions. Systems, compositions, apparatus, and methods for hydraulically fracturing a subterranean formation traversed by a wellbore including forming a base fluid with a gelling agent, forming a foam fluid with a gas and a proppant, injecting into the formation the base fluid, injecting into the formation the foam fluid, repeating the injecting the base fluid and foam fluid, and forming channels in the base fluid with faster flow than flow in the foam fluid.
A method can include receiving log data for different types of logs; identifying a portion of the log data that corresponds to a type of formation; defining combinations of the portion of the log data that correspond to the type of formation; implementing a machine learning model that generates scores for the combinations, where each of the scores indicates an ability of each of the combinations to predict one or more target logs therein as selected from the different types of logs; and outputting, based on a ranking of the scores, at least a top ranked one of the combinations that corresponds to the type of formation.
An enterprise system may include devices that perform respective operations of an enterprise and a sustainability platform system. The sustainability platform system may obtain a sustainability model representative of a state of operations of the enterprise and a current sustainability action plan associated with improving one or more sustainability parameters of the enterprise via one or more abatement technologies. The sustainability platform system may also determine that updated data is available for the abatement technologies and simulate an effect of the action plan on the sustainability parameters based on the updated data. The sustainability platform system may also determine whether the simulated effect of the action plan is effective to cause the sustainability parameters to be within one or more thresholds, and in response to determining that the simulated effect is effective, send commands to the devices to maintain their respective operations according to the current sustainability action plan.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
An enterprise system may include one or more devices that perform respective operations of an enterprise and a sustainability platform system. The sustainability platform system may obtain a sustainability model representative of a state of operations of the enterprise and a current sustainability action plan associated with improving one or more sustainability parameters of the enterprise. The sustainability platform system may also receive updated carbon credit data, simulate an effect of the current sustainability action plan on the sustainability parameters based on the updated carbon credit data (generating simulated sustainability parameters), and determine whether the current sustainability action plan is effective based on a comparison of the simulated sustainability parameters to sustainability target data. In response to determining that the current sustainability action plan is effective, the sustainability platform system may send commands to the devices to maintain their operations according to the current sustainability action plan.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
55.
UPDATING SUSTAINABILITY ACTION PLANS FOR AN ENTERPRISE BASED ON DETECTED CHANGE IN INPUT DATA
A method includes receiving datasets comprising image data, marketplace data, third-party data, internet-of-things (IoT) data, corporate data, or any combination thereof associated with enterprise operations corresponding to production data for operational tasks performed in a hydrocarbon production system, facility data for utility operations within buildings associated with the enterprise, or both. The method involves detecting a change in sustainability parameter data associated with the enterprise operations based on the datasets and a sustainability model representative of current sustainability parameters associated with the enterprise operations, updating the sustainability model based on the datasets, and sending the updated sustainability model to engineering workflow systems to determine action plans associated with improving the sustainability parameters or the additional sustainability parameters. The method may then involve sending commands to devices associated with the hydrocarbon production system, the buildings, or both based on the action plans to cause the devices to adjust their respective operations.
An enterprise system may include one or more devices that perform respective operations of an enterprise and a sustainability platform system. The sustainability platform system may obtain input data from one or more input data sources, and determine a respective authority level for each of the input data sources. The sustainability platform system may also determine uncertainty data associated with the input data based on the respective authority level for each of the input data sources, determine confidence parameters associated with the input data based on the uncertainty data, generate one or more sustainability action plans for improving the sustainability parameters of the enterprise based on the input data stored in the database, and send one or more commands to the devices to adjust their respective operations according to the one or more sustainability action plans.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
An enterprise system may include one or more devices that perform respective operations of an enterprise and a sustainability platform system that searches input data sources for abatement technologies that, when implemented, improve one or more sustainability parameters of the enterprise. The sustainability platform system may determine respective technology parameters that correlate a respective abatement technology with a respective set of the sustainability parameters that the respective abatement technology is configured to improve and one or more deployment aspects of the respective abatement technology and store the abatement technologies and respective technology parameters in a database. Additionally, the sustainability platform system may generate a sustainability action plan that implements at least one abatement technology based on a match between a deployment aspect of the enterprise and the technology parameters of the abatement technology and send commands to the devices to adjust their respective operations according to the sustainability action plan.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
A method may include receiving production data and facility data associated with an enterprise, such that the production data includes operational tasks performed in a hydrocarbon production system and facility data includes utility operations within buildings associated with the enterprise. The method may involve receiving sustainability parameter data associated with corresponding to the enterprise based on the production data and the facility data. The method may include generating a sustainability report representative of sustainability parameters associated with the operations of the enterprise based on the sustainability parameter data, sending the sustainability report to engineering workflow systems that determine action plans associated with improving the sustainability parameters associated with the one or more utility operations, and sending commands to devices associated with the buildings based on the action plans, such that the commands cause the plurality of devices to adjust their respective operations.
A method includes receiving datasets comprising image data, marketplace data, third-party data, internet-of-things (IoT) data, corporate data, or any combination thereof associated with enterprise operations corresponding to production data performed in a hydrocarbon production system, facility data associated with utility operations within buildings associated with the enterprise, or both. The method involves detecting a change in sustainability parameter data associated with the enterprise operations based on the datasets and a sustainability model, updating the sustainability model based on the datasets, sending the updated sustainability model to engineering workflow systems to determine action plans associated with improving the sustainability parameters, the additional sustainability parameters, or both. The method may involve sending commands to devices associated with the hydrocarbon production system, the buildings, or both based on the action plans, such that the commands cause the devices to adjust their operations.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
A method may include receiving production data and facility data associated with an enterprise, such that the production data includes operational tasks performed in a hydrocarbon production system and wherein the facility data includes utility operations within buildings associated with the enterprise. The method may involve receiving sustainability parameter data associated with operations corresponding to the enterprise based on the production data and the facility data, generating a sustainability report representative of sustainability parameters associated with the operations of the enterprise based on the sustainability parameter data, and sending the sustainability report to one or more engineering workflow systems to determine action plans associated with improving a portion of the sustainability parameters associated with the operational tasks. The method may then send commands to devices associated with the hydrocarbon production system based on the action plans, such that the commands cause the devices to adjust their respective operations.
A method includes receiving sustainability datasets associated with enterprise operations of an enterprise, such that the enterprise operations correspond to production data performed in a hydrocarbon production system, facility data related to utility operations within buildings associated with the enterprise, or both. The method may involve determining that one or more sustainability alerts are present for the enterprise operations based on the sustainability datasets; and identifying assets of the hydrocarbon production system, the one or more buildings, or both associated with the one or more sustainability alerts in response to determining that the one or more sustainability alerts are present. The method may include retrieving asset data associated with the assets, sending the asset data to engineering workflow systems, receiving updated action plans from the engineering workflow systems, and sending commands to devices to adjust operations based on the updated action plans.
A method may include receiving a sustainability model indicative of expected sustainability parameters associated with implementing action plans that correspond to enterprise operations of an enterprise over a period of time, such that the enterprise operations correspond to production data performed in a hydrocarbon production system, facility data corresponding to buildings associated with the enterprise, or both. The method may also include receiving an indication to optimize one sustainability parameter and identifying an engineering workflow system that improves a first sustainability parameter associated with the one sustainability parameter. The method may involve sending the sustainability model to the engineering workflow system and receiving an action plan to improve the sustainability parameter, such that commands may be sent to devices based on the action plan to cause the one or more devices to adjust one or more respective operations.
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
A method may include receiving a sustainability model indicative of a plurality of sustainability parameters associated with enterprise operations corresponding to production data for operational tasks performed in a hydrocarbon production system, facility data corresponding to utility operations within buildings associated with the enterprise, or both. The method involves simulating implementing action plans via devices that correspond to the enterprise operations over time to determine an amount of greenhouse gas (GHG) emissions associated with the enterprise over time, generating a GHG footprint evolution report based on the amount of GHG emissions, and identifying at least one of a plurality of engineering workflow systems to reduce the amount of GHG emissions based on the GHG footprint evolution report. The method involves sending commands to devices of the plurality of devices based on the action plan, such that the commands are cause the devices to adjust their operations.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
A method may include receiving a sustainability model indicative of a plurality of sustainability parameters associated with enterprise operations corresponding to production data of a hydrocarbon production system or facility data of buildings associated with the enterprise. The method includes simulating implementing action plans via a plurality of devices that correspond to the enterprise operations over time to determine an amount of greenhouse gas (GHG) emissions associated with the enterprise, identifying at least one of a plurality of engineering workflow systems to reduce the amount of GHG emissions based on the GHG emissions, such that the plurality of engineering workflow systems determines maintenance or replacement operations for equipment in the enterprise. The method includes sending commands to devices of the devices based on the action plan, such that the commands are cause the devices to go offline at a schedule time period to perform maintenance or replacement of the devices.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
G06Q 10/20 - Administration of product repair or maintenance
G06Q 10/30 - Administration of product recycling or disposal
65.
CHEMICAL COMPOSITIONS FOR GEOTHERMAL WELL STIMULATION
A method, apparatus, system, and compositions for introducing diversion agents into a subterranean formation traversed by a wellbore with a heat transfer surface, including forming a first fluid comprising a diversion agent, introducing the first fluid into a region of the formation wherein the heat transfer surface is higher than if no agent were present, and introducing a second fluid for collecting heat from the formation. A method, apparatus, system, and compositions for introducing diversion agents into a subterranean formation traversed by a wellbore with a heat transfer surface, including forming a first fluid comprising a diversion agent, introducing the first fluid into a region of the formation wherein the formation is at least 350 °F and wherein the agent maintains its mechanical integrity at least 2 hours, and introducing a second fluid to the formation.
An enterprise system may include one or more devices that perform respective operations of an enterprise and a sustainability platform system. The sustainability platform system may obtain a sustainability model representative of a state of operations of the enterprise and a currently implemented sustainability action plan associated with improving one or more sustainability parameters of the enterprise. The sustainability platform system may also receive updated regulation data, simulate an effect of the currently implemented sustainability action plan on the sustainability parameters based on the updated regulation data, generating simulated sustainability parameters, and determine whether the currently implemented sustainability action plan is effective based on a comparison of the simulated sustainability parameters to sustainability target data. In response to determining that the currently implemented sustainability action plan is effective, the sustainability platform system may send commands to the devices to maintain their operations according to the currently implemented sustainability action plan.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
An enterprise system may include one or more devices that perform respective operations of an enterprise and a sustainability platform system to determine a sentiment regarding input data by monitoring one or more input data sources based on monitoring parameters associated with aspects of sustainability of the enterprise. Additionally, the sustainability platform system may determine if changes to the input data are likely to have occurred based on the sentiment, and, if so, trigger a data search for the new input data. The sustainability platform system may also obtain the new input data via the input data sources based on the data search, generate one or more sustainability action plans for improving sustainability parameters of the enterprise based on the new input data, and send one or more commands to the devices to adjust their respective operations according to the one or more sustainability action plans.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
68.
GENERATING AND MAINTAINING A SUSTAINABILITY DATABASE FOR DETERMINING AND UPDATING SUSTAINABILITY ACTION PLANS
An enterprise system may include one or more devices that perform respective operations of an enterprise and a sustainability platform system. The sustainability platform system may obtain search parameters associated with one or more sustainability parameters of the enterprise, obtain input data from one or more input data sources, and determine confidence parameters for the input data based on the input data sources. The sustainability platform system may also store the input data and the confidence parameters in a database of the sustainability platform system, generate one or more sustainability action plans for improving the sustainability parameters of the enterprise based on the input data stored in the database, and send one or more commands to the devices to adjust their respective operations according to the one or more sustainability action plans.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
A method may include receiving production data and facility data associated with an enterprise, such that the production data includes operational tasks performed in a hydrocarbon production system, and the facility data includes one or more utility operations within one or more buildings associated with the enterprise. The method may also include receiving sustainability parameter data associated with one or more operations corresponding to the enterprise based on the production data and the facility data, generating a sustainability report representative of sustainability parameters associated with the operations of the enterprise based on the sustainability parameter data, and sending the sustainability report to one or more engineering workflow systems to determine action plans associated with improving the sustainability parameters. After receiving the action plans, the method includes sending commands to cause devices to adjust their respective operations.
An enterprise system may include one or more devices with sensors that measure operational parameters of the devices. The enterprise system may also include a sustainability platform system that obtains a sustainability model representative of a state of operations of the enterprise based on the measured operational parameters and receives sustainability target data that includes one or more threshold limits, one or more ranges, or both for one or more sustainability parameters. The sustainability platform system may also obtain one or more action plans for adjusting respective operations of the devices based on the sustainability model and the sustainability target data, simulate a performance of the action plans over a period of time relative to the sustainability parameters, and determine whether the simulated performance of the action plans is effective.
An enterprise system may include one or more facility level devices of an enterprise and a sustainability platform system that obtains a sustainability action plan associated with improving one or more sustainability parameters of the enterprise and simulates missing data relevant for measuring an effectiveness of the sustainability action plan and unavailable for use by the sustainability platform system to generate simulated sustainability data. Additionally, the sustainability platform system may determine whether the sustainability action plan is effective to cause the sustainability parameters to be within one or more target thresholds, one or more target ranges, or both based on the simulated sustainability data and in response to determining that the sustainability action plan is effective, send one or more commands to the facility level devices to cause the facility level devices to adjust one or more respective operations according to the sustainability action plan.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
An enterprise system may include one or more devices that perform respective operations of an enterprise and a sustainability platform system. The sustainability platform system may obtain a sustainability model representative of a state of operations of the enterprise and a sustainability action plan associated with improving one or more sustainability parameters of the enterprise. The sustainability platform system may also determine confidence data associated with a likelihood that the sustainability action plan will improve the sustainability parameters, simulate an effect of the sustainability action plan on the sustainability parameters based on the sustainability model and the confidence data, and determine a selection of the sustainability action plan or an alternate sustainability action plan based on the simulated sustainability parameters. In response to selection of the sustainability action plan, the sustainability platform system may send commands to the devices for adjusting their respective operations according to the sustainability action plan.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
G06Q 10/30 - Administration of product recycling or disposal
73.
IDENTIFYING ABATEMENT TECHNOLOGIES FOR IMPLEMENTATION IN SUSTAINABILITY ACTION PLANS
An enterprise system may include one or more devices that perform respective operations of an enterprise and a sustainability platform system. The sustainability platform system may obtain a sustainability model representative of a state of operations of the enterprise and sustainability target data of target constraints on one or more sustainability parameters of the enterprise. Additionally, the sustainability platform system may identify one or more abatement technologies from a database of multiple abatement technologies based on the sustainability model and the sustainability target data and generate a sustainability action plan for implementing at least one abatement technology of the identified abatement technologies such that the at least one abatement technology, when implemented via the sustainability action plan, is estimated to satisfy the sustainability target data. The sustainability platform system may also send commands to the devices to adjust their respective operations according to the sustainability action plan.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
G06Q 10/30 - Administration of product recycling or disposal
74.
EVALUATING ACTION PLANS FOR OPTIMIZING SUSTAINABILITY FACTORS OF AN ENTERPRISE
A method may include receiving a sustainability model indicative of a plurality of expected sustainability parameters associated with enterprise operations of an enterprise over a period of time. The method includes receiving a plurality of action plans for the enterprise, such that the plurality of action plans corresponds to operational characteristics of a plurality of devices that correspond to the one or more enterprise operations. The method receives sustainability variables associated with sustainability parameters for the enterprise operations, simulating a plurality of sustainability variables associated with performing the plurality of action plans over time with respect to the sustainability variables, determining a plurality of effectiveness values associated with performing the plurality of action plans relative to the sustainability variables, presenting the plurality of action plans with the one or more effectiveness values. The method includes sending commands to devices of the plurality of devices based on a selected action plan.
G06Q 10/06 - Resources, workflows, human or project managementEnterprise or organisation planningEnterprise or organisation modelling
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
Process for locating emission detecting camera(s) at a worksite. The process can include creating a site model, completing a camera coverage calculation loop that can include choosing a first camera location from the site model, and completing a source calculation loop to provide a plurality of coverage values of the first camera location for a plurality of potential emission sources in the site model. The process can also include calculating a coverage ratio from the plurality of coverage values to provide a first coverage ratio. The process can also include repeating the camera coverage calculation loop for an additional potential camera location from the site model to provide a plurality of coverage ratios. The process can also include creating an ordered list of the potential camera locations based on the coverage ratios. The process can also include choosing a camera position at the worksite from the ordered list.
A system includes a fiber optic cable configured to detect one or more first parameters of a leak event along a fluid conduit, and one or more sensors configured to measure one or more second parameters of a fluid flow along the fluid conduit. The system also includes a controller including a processor, a memory, and instructions stored on the memory and executable by the processor to: detect the one or more first parameters of the leak event via the fiber optic cable, measure the one or more second parameters of the fluid flow via the one or more sensors, input the one or more first parameters and the one or more second parameters into a model configured to simulate operation with the fluid conduit, and output leak information corresponding to the leak event via execution of the model.
G01M 3/04 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point
G01M 3/38 - Investigating fluid tightness of structures by using light
G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
G01D 21/02 - Measuring two or more variables by means not covered by a single other subclass
Methods and systems are provided for extracting thermal energy from a conventional geothermal reservoir. One aspect involves drilling or accessing a production well that intersects the conventional geothermal reservoir, and detonating at least one linear shaped charge to enlarge or open a naturally-occurring fracture of the conventional geothermal reservoir at the intersection of the naturally-occurring fracture and the production well, which reduces pressures loss of fluid flow into the production well from the naturally-occurring fracture. The reduction in pressure loss can increase fluid flow into the production well to increase the amount of captured heat. The detonation of the linear shaped charge(s) can increase aperture size of at least one naturally-occurring fracture at a wellbore surface.
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
A method can include acquiring data for rig operations that move a drillstring in a borehole in a subsurface geologic region, where the drillstring includes connected stands of drill pipe and a drill bit for drilling into the subsurface geologic region, and where the data include measured depth data, inclination data, mud density data, and measured hook load data; generating an estimated hook load value for a measured depth in the borehole using at least a trained model that receives a portion of the data as associated with the measured depth; performing a comparison between the estimated hook load value and a measured hook load value of the measured hook load data as associated with the measured depth; and, based at least in part on the comparison, determining a level of sticking of the drillstring in the borehole.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
79.
INTERVENTION COMBINATIONS TO BOOST WELL PERFORMANCE IN GEOTHERMAL SYSTEMS
Methods are provided for extracting thermal energy from a geothermal reservoir having at least one feature extending therethrough, which involve drilling or accessing a production well that intersects the at least one feature, wherein the at least one feature provides a flow path of pressurized geothermal fluid into the production well. Well log data can be analyzed to determine position of the at least one feature in the production well. One or more interventions, or combinations of interventions, can be performed to open the feature or otherwise enhance the flow rate of pressurized geothermal fluid carried by the feature into the production well. The intervention(s) can be performed on multiple features that connect to the production well. The method can also be applied to multiple production wells.
F24T 10/30 - Geothermal collectors using underground reservoirs for accumulating working fluids or intermediate fluids
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
E21B 23/06 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting packers
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
80.
AUTOMATED METHOD TO DETECT BLURRINESS AND SATURATED PIXELS FROM IMAGES
Systems and methods are provided for analyzing sample images, such as for cuttings obtained during drilling of a geologic formation. The system utilizes automated image processing to detect and correct blurriness and saturated pixels in the sample images and control related devices based on the detection. The system allows the acquisition of high quality logging curves for real-time and/or near real-time geologic formation evaluation and geosteering.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 47/002 - Survey of boreholes or wells by visual inspection
G06T 5/20 - Image enhancement or restoration using local operators
The disclosed technology is directed to methods and systems for optimizing gas storage (GS) operations. The methods comprise generating a GS model associated with a resource site such that the GS model comprises one or more parameters; determining risk thresholds for the GS operations based on risk profile data associated with the resource site; parameterizing, based on the risk thresholds, the one or more parameters; generating, using the parameterized GS model, a simulation plan for the GS operations at the resource site; executing the simulation plan across: multiple simulators in parallel, a defined uncertainty space derived from uncertainty data, multiple time periods, and the plurality of geological realizations. In some embodiments, the methods include aggregating analysis data generated from executing the simulation plan. The analysis data may indicate: gas concentration data; gas leakage data; and configuration data associated with configuring a monitoring system at the resource site.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
A system includes a digital camera deployed in an image acquisition chamber and configured to acquire a digital image of a cuttings sample. A calibration sample holder including a sample area configured to receive the drill cuttings sample and a calibration area having a color calibration region and a spatial resolution calibration region is deployed in the image acquisition chamber below the digital camera such that both the sample area and the calibration area are within a field of view of the digital camera. An electronic controller is configured to cause the digital camera to take a digital image of the calibration sample holder and evaluate a portion of the digital image including the calibration area to certify that the digital image meets or exceeds predetermined calibration standards.
A sour production fluid mitigation system may at an entry point below an injection sub for a coiled tubing system, pumping an inhibited fluid through pressure control equipment for the coiled tubing system to an exit point. A sour production fluid mitigation system may use a choke guide below the exit point and above a wellhead, maintaining an inhibited fluid pressure at the exit point greater than or equal to a production fluid pressure at a production tree of the wellhead.
A system for capturing a target species from an exhaust gas stream generated by at least one engine at a surface of a wellbore utilized in reservoir stimulation for subsurface energy recovery. The system includes a heat exchanging system for cooling the exhaust gas stream to a predetermined temperature. The system includes a water separation unit for separating a liquid from the cooled exhaust gas stream. The system includes a target species capture module for capturing the target species from the cooled exhaust gas stream. The system includes a target species regeneration module to extract the captured target species. The system includes a target species compression module for liquefying the captured target species. The system includes a target species storage module for storing the liquified target species, wherein the system is mounted on a mobile platform for transportation to and from the surface of the wellbore.
B01D 53/00 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols
B01D 53/04 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography with stationary adsorbents
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
85.
RECONSTRUCTING THREE-DIMENSIONAL SUBSURFACE IMAGE VOLUMES BASED ON TWO-DIMENSIONAL SEISMIC IMAGES
A method of generating a three-dimensional (3D) seismic image volume includes receiving a plurality of two-dimensional (2D) seismic images. The method also includes generating a proxy volume representative of a three-dimensional volume that corresponds to the 3D seismic image volume based on the plurality of 2D seismic images, the proxy volume including multiple approximated 2D seismic images. The method also includes generating an approximate image volume including a first plurality of seismic images along a first trajectory based on updating the plurality of approximated 2D seismic images via a first machine learning algorithm. Further, the method includes generating the 3D seismic image volume including a second plurality of seismic images based on updating the first plurality of seismic images via a second machine learning algorithm in a second trajectory different from the first trajectory.
86.
INTERVENTIONS TO BOOST WELL PERFORMANCE IN GEOTHERMAL SYSTEMS
Methods are provided for extracting thermal energy from a geothermal reservoir having at least one feature extending therethrough, which involve drilling or accessing a production well that intersects the at least one feature, wherein the at least one feature provides a flow path of pressurized geothermal fluid into the production well. Subsurface data can be analyzed to determine position of the at least one feature in the production well. One or more interventions, or combinations of interventions, can be performed to open the feature or otherwise enhance the flow rate of pressurized geothermal fluid carried by the feature into the production well. The intervention(s) can be performed on multiple features that connect to the production well. The method can also be applied to multiple production wells.
The invention relates to an installation (1) and method for supplying process steam by means of waste heat recovery. The installation (1) comprises heat transfer devices (6, 7) and an energy storage device (8) and is designed such that it can change configuration according to the temperature and/or flow conditions of the source.
F01K 3/14 - Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having both steam accumulator and heater, e.g. superheating accumulator
F01K 3/18 - Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein having heaters
88.
METHOD AND SYSTEM FOR PRODUCING HYDROGEN FROM A HEAT SOURCE, AND PLANT COMPRISING SUCH A SYSTEM
The invention relates to a method for producing hydrogen by steam electrolysis, using the heat from a hot effluent (102) discharged by an industrial plant, the method comprising the following steps: - heat exchange, in a heat exchanger (106), between the hot effluent (102) and a flow of water (104) in order to produce a first flow of steam (108), - cogeneration of electricity (118) and a second flow of steam (116) by a cogeneration unit (110) supplied with the first flow of steam (108), and - electrolysis of at least part of the second flow of steam (116) in an electrolysis unit (120) powered by the electricity (118), in order to produce a hydrogen flow and an oxygen-rich flow. The invention further relates to a system (100) implementing such a method and to a plant implementing such a system.
C25B 9/73 - Assemblies comprising two or more cells of the filter-press type
C25B 15/021 - Process control or regulation of heating or cooling
C25B 15/08 - Supplying or removing reactants or electrolytesRegeneration of electrolytes
F01K 3/00 - Plants characterised by the use of steam or heat accumulators, or intermediate steam heaters, therein
F01K 13/00 - General layout or general methods of operation, of complete steam engine plants
F04D 1/00 - Radial-flow pumps, e.g. centrifugal pumpsHelico-centrifugal pumps
F28B 1/00 - Condensers in which the steam or vapour is separated from the cooling medium by walls, e.g. surface condenser
F28D 1/00 - Heat-exchange apparatus having stationary conduit assemblies for one heat-exchange medium only, the media being in contact with different sides of the conduit wall, in which the other heat-exchange medium is a large body of fluid, e.g. domestic or motor car radiators
B01D 5/00 - Condensation of vapoursRecovering volatile solvents by condensation
A system for detecting methane includes a body and a shaft extending from the body. The system also includes a wind sensor coupled to the shaft. The wind sensor is configured to measure a wind direction and a wind intensity. The system also includes a pyranometer coupled to the body. The pyranometer is configured to measure ambient light. The system also includes a methane sensor positioned on or in the body. The methane sensor is configured to measure a methane concentration in ambient air.
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
G01S 19/01 - Satellite radio beacon positioning systems transmitting time-stamped messages, e.g. GPS [Global Positioning System], GLONASS [Global Orbiting Navigation Satellite System] or GALILEO
90.
AUTOMATED DIP MERGING IN VERTICAL AND HORIZONTAL WELLS
A method for computing a dip orientation of a subterranean structure from a wellbore image includes conducting a lamination analysis on a received wellbore image to identify a structure therein and to compute a plurality of dip orientations of the identified structure at a corresponding plurality of the depths. The received image is further evaluating with a classification algorithm to generate a labeled image including an image label for each of a plurality of depth zones in the received image. The plurality of computed dip orientations and the image label are evaluated for at least one of the plurality of depth zones to generate a substructure therein, wherein the substructure includes a subset of the computed dip orientations. The subset of computed dip orientations in the substructure is merged to compute at least one dip orientation for the geological layer.
A method for estimating a drill cuttings lag time during a drilling operation includes circulating drilling fluid in a wellbore to drill. A plurality of radio frequency identification device (RFID) tags and/or a colored dye are introduced into the circulating drilling fluid while drilling. Arrival times of the RFID tags or the colored dye at the surface are evaluated to estimate the drill cuttings lag time.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A method for estimating a cuttings lag time or lag time distribution during a drilling operation includes circulating drilling fluid in a wellbore while drilling. Colored magnetic markers are introduced into the circulating drilling fluid while drilling. A magnetic or electromagnetic trap is used to remove colored magnetic markers from the circulating drilling fluid. The removed colored magnetic markers are detected based upon their color using an optical sensor. Surface arrival times of the detected colored magnetic markers are evaluated to estimate the lag time or the distribution of lag times.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 31/06 - Fishing for or freeing objects in boreholes or wells using magnetic means
E21B 47/002 - Survey of boreholes or wells by visual inspection
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
93.
IMPLEMENTATION OF GENERATIVE ARTIFICIAL INTELLIGENCE IN OILFIELD OPERATIONS
A method for monitoring a risk to a stability of a wellbore in a subsurface formation includes receiving first input data representing the wellbore or the subsurface formation. The method also includes extracting parameter-value pairs from the first input data. The method also includes determining an expected pore pressure gradient based upon the parameter-value pairs. The method also includes determining an expected fracture gradient based upon the parameter-value pairs. The method also includes determining a mud weight uncertainty profile for the wellbore based upon the expected pore pressure gradient and the expected fracture gradient.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A method may include receiving, via an interface, a digital well plan for a well at a field site; automatically determining, based on a computational analysis of at least offset well data for offset wells at different field sites, a corresponding likelihood for each of a number of undesirable events for at least one section of the well specified by the digital well plan; automatically computing a potential risk metric for each of the number of undesirable events based at least in part on the corresponding likelihood for each of the number of undesirable events; and automatically generating a graphical user interface that includes a section identifier for each of the at least one section of the well, an undesirable event identifier for each of the number of undesirable events, and a potential risk identifier based on the potential risk metric for each of the number of undesirable events.
A method of imaging an earth formation comprises identifying engagement data from an engagement sensor. The engagement data corresponds to an engagement of the instrumented engagement element with a borehole in the earth formation. The method includes identifying rotation data from a rotation sensor. The rotation data corresponds to a rotational orientation of the engagement data with respect to the borehole. The method includes mapping the engagement data to the rotation data to generate oriented engagement data.
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
A method of identifying a geothermal reservoir of an earth formation comprises receiving engagement data from an engagement sensor. The engagement data corresponds to an engagement of the instrumented engagement element with a borehole in the earth formation. The method includes identifying environment data from a rotation sensor. The environment data corresponds to a downhole environment of the engagement data. The method includes mapping the engagement data to the environment data to generate mapped engagement data.
E21B 47/002 - Survey of boreholes or wells by visual inspection
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
An instrument assembly comprises an electronics housing disposed in a body of a downhole tool and an engagement element assembly connected to the electronics housing. The instrument assembly includes an engagement sensor positioned at a base of the engagement element assembly and configured to take measurements corresponding with an engagement of the engagement element assembly with a borehole. The instrument assembly includes an electronics housing seal configured to seal at least a portion of the electronics housing from a downhole pressure.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
The provided solution relates to well systems for producing various fluids, in particular for producing fluid from the hydrocarbon-bearing formation using hydraulic fracturing. The solution provides a method for hydraulic fracturing that comprises injecting a proppant-free fluid through a well into a formation to create and propagate a fracture; preparing a fracturing fluid by mixing at least water, proppant and at least the first polymer additive and the second polymer additive to produce flocculated proppant particles; injecting the fracturing fluid containing prepared flocculated proppant particles into the formation; and injecting a displacement fluid into the well. The provided method ensures placing a proppant in sufficient concentrations at a distance from the wellbore and achieving high vertical propagation of proppant across the complex fracture network.
A method includes actuating a blow-out preventer (BOP) by moving a ram using an electric motor. The method also includes capturing sensor data with one or more sensors as the BOP is electrically-actuated. The method also includes determining one or more parameters with a controller based upon the sensor data. The method also includes controlling the electric motor based upon the one or more parameters.
A bit includes a matrix body including a matrix material that is a matrix material powder bound by an infiltrant. An integral metallic connection includes a matrix portion embedded in the matrix body and a connection portion extended from the matrix body. The connection portion and the matrix portion are integrally formed with each other. The integral metallic connection has a treated strength that is greater than or equal to 90 ksi. The integral metallic connection allows for a drill bit connection to a drill string without the usage of a joining methods (2-piece construction) typical for matrix body bit constructions.
