Systems and methods presented herein are configured to generate a machine-learning (ML) backbone model for generating a fracture design output to adjust operations associated with well stimulation, fracturing, and the like. A method may include generating a synthetic physics-based dataset for hydraulic fracturing or stimulation to use machine learning or predictive modeling. The method may also include generating a machine-learning (ML) model using the synthetic physics-based dataset. The method may also include combining a real fracturing dataset with the synthetic physics-based dataset and retrain ML model using a transfer learning approach. Further, the method may include adjusting a hydraulic fracturing operation, a stimulation operation, or both, using the ML model.
Embodiments presented provide for a method to reduce water utilization in industrial processes. Example embodiments provide reduction of both water utilization and carbon dioxide emissions during stimulation procedures during hydrocarbon recovery operations.
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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
G01V 3/32 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
Systems and methods of the present disclosure provide systems and methods for receiving one or more sets of parameters related to an operation corresponding to a wellbore. At a first time, the operation is simulated using the one or more sets of parameters and at least one simulator. Pertinent results from the simulation are recorded and stored in a table. The pertinent results include at least one constraint. At a second time, the constraint is retrieved from the table for performance of the operation, and the constraint is used to control the operation.
A method for operating an unmanned autonomous vehicle includes autonomously maneuvering the unmanned autonomous vehicle about a facility, collecting gas concentration data using one or more sensors carried on or integrated with the unmanned autonomous vehicle, monitoring the collected gas concentration data to detect a high concentration due to a gas leak. The method further includes, if a high concentration is detected, estimating a location of the gas leak and maneuvering the unmanned autonomous vehicle toward the estimated location of the gas leak.
G05D 1/689 - Pointing payloads towards fixed or moving targets
G01N 1/00 - SamplingPreparing specimens for investigation
G05D 105/85 - Specific applications of the controlled vehicles for information gathering, e.g. for academic research for patrolling or reconnaissance for police, security or military applications
G05D 105/80 - Specific applications of the controlled vehicles for information gathering, e.g. for academic research
G05D 107/70 - Industrial sites, e.g. warehouses or factories
5.
SELF-CONSISTENT FLOW REGIME IDENTIFICATION FOR DOWNHOLE MONITORING
Systems and methods of the present disclosure include receiving measured data corresponding to a wellbore and locating the measured data in a flow map corresponding to the wellbore. The method also includes converting the measured data to determine friction loss and comparing the located measured data and the determined friction loss. Moreover, the method also includes determining that the located measured data is consistent with the determined friction loss with a common flow regime and deeming the common flow regime as a current flow regime. Furthermore, the method includes controlling an operation in the wellbore based at least in part on the deemed current flow regime.
E21B 47/10 - Locating fluid leaks, intrusions or movements
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 5/04 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
A method for determining a maximum tripping velocity for tripping a downhole tool string in a wellbore includes obtaining contextual data including wellbore data, tool string data, and drilling fluid data; computing downhole drilling fluid pressures at multiple tool string velocities and accelerations using the obtained contextual data and a wellbore hydraulics model; generating an equivalent circulation density (ECD) contour along a two-dimensional acceleration and velocity parameter space from the computed downhole drilling fluid pressures; and evaluating the ECD contour with at least one of a formation pore pressure or a formation fracture pressure to generate the maximum tripping velocity.
A system includes an interconnection terminal box connected to a plurality of core components in an integrated system. Through disconnection of one or more core components of the plurality of core components from the interconnection terminal box, the system is configured to individually test a at least one core component of the plurality of core components that remains connected to the interconnection terminal box, and through connection of the plurality of core components to the interconnection terminal box, the system is configured to test the integrated system as a whole.
Embodiments presented provide for a characterization of water-oil mixtures. In embodiments, electrical conductivity measurements are used to characterize water-oil mixtures.
Geopolymer precursor compositions are presented that are useful for cementing a subterranean well, among other uses. The precursor compositions are dry mixtures that have an aluminosilicate source and an activator. The activator is an alkalinity source that is safe to store, transport, and blend with an aluminosilicate source. The activator may be a hydroxide-free activator. A geopolymer slurry is formed by adding water to the dry geopolymer precursor compositions. Such slurries have suitable characteristics for use in cementing applications that use pumpable mixtures.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 22/10 - Acids or salts thereof containing carbon in the anion, e.g. carbonates
C04B 24/38 - Polysaccharides or derivatives thereof
C04B 28/00 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
Geopolymeric compositions are presented that are useful as geopolymer slurries for cementing subterranean wells. The slurries may contain an aluminosilicate source, an alkaline source and a carrier fluid. The slurries generate an alkali metal or alkaline earth hydroxide activator in situ, thereby avoiding or reducing handling of alkali materials at a wellsite.
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C04B 28/00 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
A metal-organic framework (MOF) may include a body including a MOF crystal having a composition selected to selectively extract one or more elements of interest from an aqueous solution. The MOF may include a plurality of MOF crystals bound by a bonding agent.
B01J 20/22 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising organic material
B01D 15/20 - Selective adsorption, e.g. chromatography characterised by constructional or operational features relating to the conditioning of the sorbent material
B01J 20/28 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof characterised by their form or physical properties
A technique facilitates long-term operation of a submersible pump which may be used in an electric submersible pumping system. According to an embodiment, the submersible pump comprises at least one stage, e.g. a plurality of stages. Each stage uses an impeller which may be rotated within a diffuser to establish a fluid flow through the pump. Additionally, each stage comprises an erosion control system positioned between the impeller and the diffuser to reduce erosion and/or the effects of erosion so as to extend the life of the submersible pump.
Branched and crosslinked polymeric fluid loss control agents and methods are provided that have at least one acrylamide-based monomer, at least one sulfonated anionic monomer, and at least one crosslinking monomer. The at least one acrylamide-based monomer and the at least one sulfonated anionic monomer are crosslinked. The branched and crosslinked polymeric fluid loss control agents have between 50 and 99 mol % of the at least one acrylamide-based monomer, between 1 and 30 mol % of the at least one sulfonated anionic monomer, and between 0.1 and 10 mol % of the at least one crosslinking monomer.
Systems and methods are described for identifying and validating a fugitive gas leak. The system identifies the onset of a leak, tracks its persistence, and subsequently, notes its gradual disappearance after repairs are initiated. The method comprises initiating an observation period which serves to characterize the behavior of the anticipated leak if it exists. Extracting the underlying distributions of the parameter space for the anticipated leak over an observation period. Data is collected over incremental steps and compared to the current reference distributions. When the test period is complete, the observation window is moved forward to include the data over the validation span. The procedure thus repeats, with an updated reference distribution and re-initialized validation period.
G01D 1/14 - Measuring arrangements giving results other than momentary value of variable, of general application giving a distribution function of a value, i.e. number of times the value comes within specified ranges of amplitude
G01M 3/02 - Investigating fluid tightness of structures by using fluid or vacuum
G01P 5/00 - Measuring speed of fluids, e.g. of air streamMeasuring speed of bodies relative to fluids, e.g. of ship, of aircraft
G01P 13/00 - Indicating or recording presence or absence of movementIndicating or recording of direction of movement
15.
SOLVENT SYSTEMS FOR CARBON DIOXIDE CAPTURE AND METHODS OF MAKING AND USING SAID SYSTEMS
Amine-based solvents, carbon dioxide capture systems, and methods for improving stability of carbamate during carbon dioxide capture are disclosed herein. The amine-based solvents comprise at least one cyclic amine having a first molecular site that is structurally modified to be protonated and a second molecular site that is structurally modified to hold carbon dioxide as carbamate. The carbon dioxide capture systems comprise at least one gaseous stream comprising carbon dioxide and the amine-based solvent in contact with the at least one gaseous stream. The methods for carbon dioxide capture comprise contacting at least one modified cyclic amine to a gaseous stream comprising carbon dioxide such that the modified at least one cyclic amine chemically reacts with carbon dioxide to form a soluble compound.
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
Systems and methods of the present disclosure include receiving measured data corresponding to a wellbore and locating the measured data in a flow map corresponding to the wellbore. The method also includes converting the measured data to determine friction loss and comparing the located measured data and the determined friction loss. Moreover, the method also includes determining that the located measured data is consistent with the determined friction loss with a common flow regime and deeming the common flow regime as a current flow regime. Furthermore, the method includes controlling an operation in the wellbore based at least in part on the deemed current flow regime.
A packer includes a cylinder of elastomer including: two flat ends, a longitudinal axis, an opening formed along the longitudinal axis, the opening configured to accommodate a cable, and at least one contact pressure feature running around a circumference of the cylinder. The cylinder is split perpendicular to the flat ends into two halves.
Cementing compositions contain water, a cement and an additive for adjusting thermal conductivity. The additive for adjusting thermal conductivity may be graphite, graphene, aluminum oxide, hematite, copper metal, copper oxide, aluminum, amorphous carbon, gallium metal, iron metal, magnesium oxide, nickel metal, nickel oxide, tin metal, tin oxide, zinc metal or zinc oxide, or combinations thereof. Such compositions may have thermal conductivities exceeding 2 W/mK. Such compositions may be useful in closed loop geothermal completions or for encasing electrical cables.
C04B 111/00 - Function, property or use of the mortars, concrete or artificial stone
C09K 5/14 - Solid materials, e.g. powdery or granular
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
A system and method for producing hydrocarbons from a well with a dual sleeve valve assembly. The dual sleeve valve assembly has a toe valve assembly and a production assembly. The toe valve assembly has a valve sleeve positioned in a valve housing comprising at least one fracturing port. The valve sleeve is shiftable to allow fluid through the least one fracturing port. The production assembly comprises a production sleeve positioned within a production outer housing comprising at least one screen port and at least one production port. A sand screen assembly disposed around the production outer housing. The production sleeve shiftable by a ball to allow fluid through the at least one screen port and the at least one production port.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/06 - Valve arrangements for boreholes or wells in wells
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
Described herein are implosion devices for use in a subterranean setting. These implosion devices use no explosives, and so create no combustion products within the subterranean environment. These implosion devices also capture all material used to create the implosion for easy removal from the subterranean environment. The implosion devices generally have an implosion chamber, a stretchable sleeve surrounding the implosion chamber, and a non-explosive initiator for imploding the implosion chamber.
E21B 37/08 - Methods or apparatus for cleaning boreholes or wells cleaning in situ of down-hole filters, screens, or gravel packs
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
21.
NANODIAMOND WITH VACANCY DEFECT AND QUANTUM DOT LUMINESCENCE
Luminescent diamond is made by subjecting a volume of diamond grains to high-pressure/high-temperature conditions with or without a catalyst or pressure transfer media to cause the grains to undergo plastic deformation to produce internal vacancy defects, increasing the luminescent activity/intensity of the resulting diamond material. The luminescent material is then subjected to further treatment to create quantum dots on the surface of the diamond particles. Quantum dot formation can include placing the diamond particles in liquid and subjecting the particles to laser pulses. The consolidated diamond material may be treated to further increase luminescent activity/intensity including reducing the consolidated diamond material to diamond particles, heat treatment in vacuum, and/or air heat treatment. The resulting luminescent diamond particles display a level of luminescence intensity greater than that of conventional luminescent nanodiamond, and may be functionalized for use in biological applications.
A method of operating a ground-source heat pump includes generating a thermal power based on a thermal communication of the ground-source heat pump with a borefield, the thermal power at least partly covering a thermal load of a facility. The method includes receiving a temperature associated with the borefield and controlling the thermal power based on the temperature. The method further includes maintaining the temperature within a temperature range based on controlling the thermal power, wherein the ground-source heat pump is configured to cause the temperature to fall outside of the temperature range at a full capacity of the thermal power.
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
23.
SYSTEMS AND METHODS FOR GAS LEAK DETECTION USING UNMANNED AUTONOMOUS VEHICLES
A method of operation of an unmanned autonomous vehicle includes autonomously maneuvering the unmanned autonomous vehicle about a facility, collecting gas concentration data using one or more sensors carried on or integrated with the unmanned autonomous vehicle, and monitoring the collected gas concentration data to detect a high concentration due to a gas leak. The method further includes, if a high concentration is detected, estimating a location of the gas leak and maneuvering the unmanned autonomous vehicle toward the estimated location of the gas leak.
A method of detecting wear of a downhole tool implemented in a subject wellbore includes receiving offset wellbore data for one or more offset wellbores and, based on the offset wellbore data, determining an expected downhole tool index for the downhole tool at one or more measurement depths including an active measurement depth of the subject wellbore. The method further includes receiving subject wellbore data and, based on the subject wellbore data, determining a subject downhole tool index in real time for the downhole tool at the active measurement depth. The method further includes determining the wear of the downhole tool based on comparing the subject downhole tool index to the expected downhole tool index at the active measurement depth in real time.
E21B 21/12 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using drilling pipes with plural fluid passages, e.g. closed circulation systems
E21B 45/00 - Measuring the drilling time or rate of penetration
A system for generating electrical power may include a flowline having an inlet that receives reservoir fluid at a first pressure, an outlet that outputs the reservoir fluid at a second pressure, a first flow path between the inlet and the outlet, and a second flow path between the inlet and the outlet, in parallel with the first flow path. The difference between the first pressure and the second pressure may include a pressure differential, and the system may include a valve that adjusts the pressure differential. Additionally, the system may include a turbine disposed along the second flow path that generates mechanical energy from a flow of the reservoir fluid induced by the pressure differential, and the mechanical energy may be converted to electrical energy.
F03G 7/04 - Mechanical-power-producing mechanisms, not otherwise provided for or using energy sources not otherwise provided for using pressure differences or thermal differences occurring in nature
E21B 41/00 - Equipment or details not covered by groups
26.
HYBRID CARBON CAPTURE SYSTEM WITH SORBENT CAPTURE STATE
A first subsystem receives a gas flow comprising a first concentration of carbon dioxide. The first subsystem separates the gas flow into a rich stream and a lean stream by a first carbon capture process. The rich stream includes a second concentration of carbon dioxide greater than the first concentration. The lean stream includes a third concentration of carbon dioxide less than the first concentration. A second subsystem receives the lean stream from the first subsystem. A carbon adsorption system removes at least a portion of the carbon dioxide from the rich stream, resulting in a depleted stream. A flow separator separates the depleted stream into a stack stream and a recycling stream. A carbon desorption system releases the portion of the carbon dioxide into the recycling stream. The recycling stream is directed to mix with at least one of the gas flow or the rich stream.
B01D 53/22 - 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 diffusion
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
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
Well spacer materials containing a small amount of cement raw material are used to precede pumping cement precursors into a well. Use of cement raw material in the spacer material reduces hardening loss in the cement at the interface with the spacer material. The cement raw material can be a cement reactant or an activator.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
28.
METHOD OF VISCOSIFYING WATER-BASED EPOXY RESIN CONSOLIDATION FLUID
Embodiments herein relate to apparatus, compositions, and methods for using a resin consolidation system in a subterranean formation traversed by a wellbore including forming a consolidation treatment fluid using an aqueous solvent, a viscosifying agent, a resin, a curing agent, and a surfactant and introducing the treatment fluid into the formation. In some embodiments, the viscosifying agent includes xanthan, guar, biopolymers, synthetic polymers, viscoelastic surfactants, polyacrylamide, hydroxyethyl cellulose (HEC), carboxymethyl cellulose (CMC), viscoelastic surfactant, or a combination thereof. In some embodiments, the curing agent includes a water-soluble polyamine-based epoxy curing agent. In some embodiments, the resin includes a polymerizable epoxy compound having at least one epoxy group per molecule. In some embodiments, the surfactant includes nonionic and amphoteric surfactant, anionic and cationic surfactant, polymeric surfactant, or a combination thereof. The treatment fluid may further include an oxidative breaker solution.
A method is disclosed that includes preloading a first set of fasteners of multiple fasteners in a first spaced arrangement around a bolt circle, wherein preloading the first set includes a first sequence starting at a first position, and preloading a second set of fasteners of the multiple fasteners in a second spaced arrangement around the bolt circle, wherein preloading the second set includes a second sequence starting at a second position, wherein a first subset includes one or more fasteners of the multiple fasteners are disposed at one or more first intermediate positions between the first and second positions.
Systems and methods of the present disclosure provide systems and methods for receiving one or more sets of parameters related to an operation corresponding to a wellbore. At a first time, the operation is simulated using the one or more sets of parameters and at least one simulator. Pertinent results from the simulation are recorded and stored in a table. The pertinent results include at least one constraint. At a second time, the constraint is retrieved from the table for performance of the operation, and the constraint is used to control the operation.
A method includes receiving field seismic data that represents a subsurface, identifying features in the field seismic data using a machine learning model that was trained using at least one first synthetic seismic data set that includes one or more features and one or more labels of the features, and at least one second synthetic seismic data set, the first and second synthetic seismic data sets both generated based on a geological model. Noise is injected into the second synthetic seismic data based on the geological model. The method also includes generating a model of the subsurface based at least in part on the features that were identified in the field seismic data using the machine learning model.
A technique facilitates perforating operations. According to an embodiment, a perforating gun system utilizes a plurality of modular perforating gun sections which are readily assembled to create a perforating gun with a desired number and orientation of shaped charge holders. In some applications, the modular perforating gun sections may be formed of plastic, e.g. injection moldable plastic, to further reduce costs and provide great flexibility with respect to construction of the desired perforating gun.
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 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
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
G01L 5/00 - Apparatus for, or methods of, measuring force, work, mechanical power, or torque, specially adapted for specific purposes
According to various embodiments, techniques for providing a subsurface master record for a subsurface data record are presented. The techniques include: determining at least one subsurface data record for mastering; obtaining a respective subsurface master record that matches the at least one subsurface data record; and merging the at least one subsurface data record with the respective subsurface master record. The techniques may also include updating each subsurface data record of the at least one subsurface data record with an indication of a relationship between the each subsurface data record and the respective subsurface master record.
G06F 7/14 - Merging, i.e. combining at least two sets of record carriers each arranged in the same ordered sequence to produce a single set having the same ordered sequence
A method of operating a thermal system implementing a ground-source heat pump includes receiving design parameters associated with a design of the thermal system and receiving one or more measurement inputs associated with a flow of a thermal fluid through a borefield of a ground heat exchanger. The method further includes, based on the measurement inputs and the design parameters, predicting one or more predicted thermal values of the thermal fluid using a forward model. The method further includes predicting one or more predicted borefield parameters of the borefield based on inverting the forward model. The method further includes monitoring the thermal system based on the predicted borefield parameters.
F24T 10/13 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes
A method for deploying a tool in a well on an electrical cable comprises attaching a cable suspension and recovery device to the cable at a position chosen such that the device is disposed below a wellhead at an upper end of the well when the tool is disposed at a selected depth in the well. The device has a diameter larger than a landing profile disposed in the well, the device having a diameter enabling free movement through the well and flow of fluid around the device in the well. The tool is attached to an end of the cable. The tool is deployed in the well by extending the cable.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
Embodiments presented provide for cable connections that may be used for downhole operations. In embodiments, cable sockets and structural unloading arrangements are used with composite cables to structurally unload data carrying inner core cable components, thereby increasing service life.
H02G 1/14 - Methods or apparatus specially adapted for installing, maintaining, repairing, or dismantling electric cables or lines for joining or terminating cables
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
Amine-based solvents, carbon dioxide capture systems, and methods for improving stability of carbamate during carbon dioxide capture are disclosed herein. The amine-based solvents comprise at least one cyclic amine having a first molecular site that is structurally modified to be protonated and a second molecular site that is structurally modified to hold carbon dioxide as carbamate. The carbon dioxide capture systems comprise at least one gaseous stream comprising carbon dioxide and the amine-based solvent in contact with the at least one gaseous stream. The methods for carbon dioxide capture comprise contacting at least one modified cyclic amine to a gaseous stream comprising carbon dioxide such that the modified at least one cyclic amine chemically reacts with carbon dioxide to form a soluble compound.
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 method for deploying a tool in a well on an electrical cable comprises attaching a cable suspension and recovery device to the cable at a position chosen such that the device is disposed below a wellhead at an upper end of the well when the tool is disposed at a selected depth in the well. The device has a diameter larger than a landing profile disposed in the well, the device having a diameter enabling free movement through the well and flow of fluid around the device in the well. The tool is attached to an end of the cable. The tool is deployed in the well by extending the cable.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
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
40.
SYSTEM AND METHOD FOR OPERATING GROUND-SOURCE HEAT PUMPS
A method of operating a ground-source heat pump (502) includes generating a thermal power based on a thermal communication of the ground-source heat pump (502) with a borefield (508), the thermal power at least partly covering a thermal load of a facility. The method includes receiving a temperature associated with the borefield (508) and controlling the thermal power based on the temperature. The method further includes maintaining the temperature within a temperature ranged based on controlling the thermal power, wherein the ground-source heat pump (502) is configured to cause the temperature to fall outside of the temperature range at a full capacity of the thermal power.
F24T 10/13 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes
F24D 3/18 - Hot-water central heating systems using heat pumps
A device, includes a hydraulic unit configured to be fluidly connected to a geothermal loop, a sensor configured to measure at least a parameter of a fluid circulating in the geothermal loop and through the hydraulic unit, wherein the parameter comprises at least one of: pressure, flow rate, temperature, density, and viscosity of the fluid circulating in the geothermal loop, and a computing device comprising a processor and a memory, wherein the computing device is configured to receive data from the sensor, calculate, via the processor, a pressure loss based on the data, and determine, based on the pressure loss in view of a predetermined theoretical pressure loss of the geothermal loop, if an integrity of the geothermal loop corresponds to a predetermined criteria to test the integrity of the geothermal loop.
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
F03G 7/04 - Mechanical-power-producing mechanisms, not otherwise provided for or using energy sources not otherwise provided for using pressure differences or thermal differences occurring in nature
Methods and systems are provided that calculate data representing an estimate of formation strength while drilling. The methods and systems employ a drill bit that is instrumented with a first sensor and a second sensor. A processor is configured to i) determine and store first data representing cutting forces acting on a cutting element of the drill bit while drilling based on measurements of the first sensor while drilling, ii) determine and store second data representing depth of cut of the drill bit while drilling based on measurements of the second sensor while drilling, and iii) process the first data and second data to generate and store data representing contact stress against the formation while drilling. This resultant data can be used as an estimate of formation strength. This estimate of formation strength is similar to UCS and can be used in oilfield operations/planning, such as formation characterization while drilling, or drilling efficiency analysis while drilling.
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 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
E21B 47/026 - Determining slope or direction of penetrated ground layers
E21B 47/26 - Storing data down-hole, e.g. in a memory or on a record carrier
A method for processing a PCD element includes placing the PCD element in a vessel. A first fluid may be applied to the PCD element when the PCD element is in the vessel. A second fluid may be applied to the PCD element when the PCD element is in the vessel. A first temperature may be applied to the PCD element when the PCD element is in the vessel. A second temperature may be applied to the PCD element when the PCD element is in the vessel.
The disclosure relates to an emission detector for monitoring methane emissions at one or more industrial facilities. The emission detector includes: an enclosure that supports a plurality of sensors, wherein the enclosure is configured to permit atmospheric gas to flow by diffusion into space at or near the plurality of sensors, wherein the plurality of sensors include at least one atmospheric sensor configured to measure atmospheric properties of the atmospheric gas that flows into the space at or near the plurality of sensors as well as at least one gas sensor configured to measure concentration of methane in the atmospheric gas that flows into the space at or near the plurality of sensors.
A method includes receiving baseline data representing an area corresponding to a first time. receiving first measurement data representing a first portion of the area corresponding to a second time subsequent to the first time. training a machine learning model to reduce an influence of a non-repeatability factor based on a combination of the baseline data and the first measurement data. receiving second measurement data representing a second portion of the area corresponding to the second time. the second portion of the area including a feature of interest that was not present at the first time or that has changed between the first and second times. and modifying the second measurement data using the machine learning model to remove the non-repeatability factor in the second measurement data.
A computational framework can include a network interface that receives data from multiple field sites; a processor-based predictor that utilizes at least a portion of the data to generate predictions for production and emissions at each of the multiple field sites; and a processor-based pathway generator that utilizes the predictions to generate an action pathway with different actions for implementation at one or more of the multiple field sites.
A method can include receiving seismic data of a seismic survey of a subsurface region; performing a full waveform inversion using the seismic data and a model of the subsurface region to determine one or more characteristics of the subsurface region, where the model of the subsurface region includes one or more angle-dependent model parameters; and outputting the one or more characteristics of the subsurface region.
An apparatus can have a seal module located at an upper portion thereof. The apparatus can also have a mud line formed through the upper portion of the apparatus and a mud outlet in fluid communication with the mud line. The apparatus can also include a mud pulser adjacent the mud outlet, wherein the mud pulser is configured to be actuated to open, partially close, and close the mud outlet.
E21B 47/18 - 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 using acoustic waves through the well fluid
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
E21B 23/08 - Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
A method of detecting wear of a downhole tool implemented in a subject wellbore includes receiving offset wellbore data for one or more offset wellbores and, based on the offset wellbore data, determining an expected downhole tool index for the downhole tool at one or more measurement depths including an active measurement depth of the subject wellbore. The method further includes receiving subject wellbore data and, based on the subject wellbore data, determining a subject downhole tool index in real time for the downhole tool at the active measurement depth. The method further includes determining the wear of the downhole tool based on comparing the subject downhole tool index to the expected downhole tool index at the active measurement depth in real time.
E21B 41/00 - Equipment or details not covered by groups
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
Systems and methods for processing vertical seismic profile (VSP) data based on an elastic waveform inversion (EWI). The EWI uses P-wave or S-wave velocity and density information above a total depth of a well and the VSP data to invert parameters including a one dimensional (1D) depth, P-wave or S-wave velocity, density, and attenuation below the total depth. The EWI includes computing a template reflection and searching potential reflections using a cross-correlation between the template reflection and the VSP data. The EWI includes a grid search used to invert the parameters for each subsurface layer below the total depth and a fine-tuning to optimize the inverted parameters based on a downhill simplex method.
Embodiments presented provide for using machine learning-based models in hydrocarbon recovery projects. In embodiments, stimulation efficiency is determined through a machine learning based model to enhance hydrocarbon recovery in wellbore applications. A method may include providing a computer model configured to use artificial intelligence. The method may include feeding the computer model data obtained from one of an optic-acquired vibration dataset and a fiber optic cable dataset, and training the computer model on the optic-acquired vibration dataset and the fiber optic cable dataset. The method may include obtaining surface data and inputting the surface data into the computer model, and predicting stimulation efficiency of a wellbore treatment for the wellbore based upon the surface data.
A method for determining a state variable representing a subsurface formation includes receiving a state variable representing a subsurface formation. The state variable includes a time stamp with a current value and a predicted value associated therewith. The method also includes evaluating a partial differential equation (PDE) based upon the state variable using a numerical simulator. The PDE is evaluated for the current value and/or the predicted value. The method also includes evaluating a matrix based upon the PDE using the numerical simulator. The method also includes determining a gradient based upon the matrix using the numerical simulator. The method also includes training a machine-learning (ML) model to produce a trained ML model. The ML model is trained based upon the gradient. The method also includes updating the state variable using the trained ML model to produce an updated state variable.
The disclosed methods include: determining a central reference point for fluid migration associated with the stored subsurface fluid; generating a radial coverage detection space extending from the central reference point for the fluid migration associated with the stored subsurface fluid; initializing a subsurface computing model for the stored subsurface fluid; overlaying the radial coverage detection space or detection system over the subsurface model for the stored subsurface fluid; execute one or more simulations by adapting or varying the one or more parameters of the subsurface computing model based on fluid plume data or fluid pressure data associated with the stored subsurface fluid; generating, based on the fluid plume data or fluid pressure data, spatial or temporal fluid distribution data associated with the stored subsurface fluid; and generating, based on the spatial or temporal fluid distribution data, PP data and PS data associated with the stored subsurface fluid.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
A method can include receiving seismic data of a seismic survey of a subsurface region; performing a full waveform inversion using the seismic data and a model of the subsurface region to determine one or more characteristics of the subsurface region, where the model of the subsurface region includes one or more angle-dependent model parameters; and outputting the one or more characteristics of the subsurface region.
Embodiments presented provide for a shifting tool comprising a body with a set of paired arms coupled to the body, and a movable sleeve housing the body and the set of paired arms. When the movable sleeve moves to a first position, the set of paired arms is uncovered and extends to engage an equipment. When the movable sleeve moves to a second position, the set of paired arms is suppressed and retracts to disengage the equipment.
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 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 33/128 - PackersPlugs with a member expanded radially by axial pressure
The present disclosure generally relates to systems and methods for determining clay content of porous media based on electromagnetic measurements and temperature gradient analysis. For example, in certain embodiments, a method includes sampling porous media of a reservoir formation; measuring a first resistivity value of the porous media at a first temperature; heating the porous media to a second temperature using a heating source; measuring a second resistivity value of the porous media at the second temperature; and determining whether the porous media contains clay based at least in part on the first and second resistivity values.
G01N 27/14 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of an electrically-heated body in dependence upon change of temperature
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
G01N 1/44 - Sample treatment involving radiation, e.g. heat
G01V 3/20 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with propagation of electric current
A computational framework can include a graphical user interface (GUI) generator; a logic generator; and a graphics generator, where the GUI generator generates a GUI for configuring a system of well equipment based on selections of graphical menu items, where the GUI dynamically responds to an interactive selection of one of the graphical menu items based on logic generated by the logic generator, and where the graphics generator generates a vector graphics representation of the system of well equipment as configured.
A method can include generating a graphical user interface that includes vector graphics representations of equipment of a system for well operations, a data graphic for rendering sensor data of the system, and a graphical control actuatable to issue a control instruction for control of the system, where the system includes an uninterruptible power supply (UPS) and a blowout preventer (BOP), and where the UPS is selectively, operatively coupled to one or more electric actuators for changing a state of the BOP; responsive to operation of the system, receiving sensor data; and updating the data graphic based at least in part on the sensor data.
E21B 47/18 - 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 using acoustic waves through the well fluid
An improved downhole locking mechanism which may include a housing releasably connected to a downhole tool. The housing includes a first housing connected to a second housing. A sleeve disposed within the second housing. A coupling connecting the sleeve and a completion or another assembly. A piston disposed within the sleeve and retained in a locked position via a shear assembly. The piston maintains a retainer in the locked position, where the retainer engages both the sleeve and the lower housing. Hydraulic pressure within the bore of the locking mechanism causes the piston to shear the shear assembly and axially shift the piston towards the upper housing. Shifting the piston causes the retainer to move radially inward to an unlocked position and disengaging the sleeve from the lower housing and unlocking the locking mechanism.
Described herein are methods and apparatus for idling a hydrocarbon well. A downhole tool is described that includes a tubular support and an explosive charge disposed within the tubular support, the explosive charge comprising a casing having the form of a cylinder with a wedge portion removed to form a wedge opening and a shaped charge shaped to fit the wedge opening. Methods described herein include positioning a partial radial cutter near an interior wall of a well completion tubing of a hydrocarbon well at a location opposite from an accessory conduit disposed in the well outside the well completion tubing, with the discharge portion of the partial radial cutter facing the interior wall of the well completion tubing, and discharging the partial radial cutter to penetrate a portion of the interior wall and sever the accessory conduit.
E21B 29/02 - 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 by explosives or by thermal or chemical means
A system includes a programmable logic controller (PLC); a primary master device; a standby master device; and a plurality of slave devices, wherein the primary master device is configured to communicate with each of the plurality of slave devices, and wherein the PLC is configured to determine that the primary master device is in a failure state, and in response, the PLC is configured to switch from the primary master device to the standby master device such that the standby master device is configured to communicate with each of the plurality of slave devices.
H04L 41/0668 - Management of faults, events, alarms or notifications using network fault recovery by dynamic selection of recovery network elements, e.g. replacement by the most appropriate element after failure
H04L 43/0817 - Monitoring or testing based on specific metrics, e.g. QoS, energy consumption or environmental parameters by checking availability by checking functioning
62.
SYSTEMS AND METHODS FOR RANGING AND TRACKING WHILE DRILLING MULTIPLE GEOLOGICAL WELLS
A system includes a first rotary steerable tool configured to control a first drilling bit to drill a first well having a first well path. The first rotary steerable tool includes a first direction and inclination component that includes a first set of sensors configured to detect a static magnetic field and a signal source configured to generate a source signal. The system also includes a second rotary steerable tool configured to control a second drilling bit to simultaneously drill a second well having a second well path that tracks the first well path. The second rotary steerable tool includes a second direction and inclination component that includes a second set of sensors configured to detect the source signal.
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
E21B 47/18 - 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 using acoustic waves through the well fluid
63.
SYSTEM AND METHODS TO MODEL PLUG UNSEATING BASED ON WELLBORE FLOW
Systems and methods presented herein relate to techniques for modeling forces subjected to a plug (e.g., formed of a diversion material) and determining a plug unseating output that may provide a remedy to a plug unseating.
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 33/16 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes using plugs for isolating cement chargePlugs therefor
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
64.
METHOD FOR SINGLE-STAGE TREATMENT OF SILICEOUS SUBTERRANEAN FORMATIONS
An aqueous composition includes an acid, or an ammonium or salt thereof; a hydrogen fluoride (HF) source; and a fluoride scale inhibitor. Various methods include providing an aqueous composition that includes an acid, or an ammonium or salt thereof, a HF source, and a fluoride scale inhibitor; and performing a treatment operation using the aqueous treatment composition.
C09K 8/528 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
E21B 43/27 - Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
A subsea vertical Xmas Tree ("XT") for a wellhead includes a roof. The roof is configured to receive and support a remotely operated vehicle (ROV) thereon. The ROV may perform operations on the XT whilst supported on the roof. The XT may further include any combination of support members, a shelf, and a component funnel. Additional systems, devices, and methods are also disclosed.
E21B 33/035 - Well headsSetting-up thereof specially adapted for underwater installations
E21B 33/076 - Well headsSetting-up thereof having provision for introducing objects or fluids into, or removing objects from, wells specially adapted for underwater installations
E21B 41/00 - Equipment or details not covered by groups
66.
Bottom hole assembly having three-point contact for improved steering
A system includes a bottom hole assembly (BHA) that includes a drill bit configured to drill a pilot hole in a subterranean formation, such that the drill bit provides a first point of contact between the BHA and the subterranean formation. The BHA includes a steering pad assembly that includes one or more steering pads each configured to move over a path of travel between a retracted position and an extended position to provide a second point of contact between the BHA and the subterranean formation, and a reamer configured to expand the pilot hole into a borehole, such that the reamer provides a third point of contact between the BHA and the subterranean formation. The system includes a controller configured to steer the BHA via the first, second, and third points of contact and adjustments to the second point of contact via control of the steering pad assembly.
The disclosure relates to a system for monitoring methane emissions at industrial facilities. The system includes a network of methane emission detectors at different locations within at least one industrial facility; a gateway device operably coupled to the network of methane emission detectors; and a cloud computing environment operably coupled to the gateway device; wherein the network of methane emission detectors is configured to perform time-series measurements at different locations within the at least one industrial facility and wirelessly communicate time-series sensor data representing such measurements to the gateway device; wherein the gateway device is configured to process the time-series sensor data to derive time-series operational data and communicate the time-series operational data to the cloud computing environment; and wherein the cloud computing environment is configured to receive and process the time-series operational data to detect and characterize methane emission at the at least one industrial facility.
G05B 19/418 - Total factory control, i.e. centrally controlling a plurality of machines, e.g. direct or distributed numerical control [DNC], flexible manufacturing systems [FMS], integrated manufacturing systems [IMS] or computer integrated manufacturing [CIM]
G01N 33/00 - Investigating or analysing materials by specific methods not covered by groups
68.
DIGITAL FRAMEWORK FOR DESIGN AND SELECTION OF PARAFFIN INHIBITORS
A method of selecting paraffin inhibitors for a target crude oil includes inputting one of more known properties of a target crude oil into a machine learning model and extrapolating unknown properties of a historical data set using a machine learning model. The machine learning model is trained on the historical data set that includes one or more properties of a plurality of crude oils, one or more properties of a plurality of paraffin inhibitors, and one or more paraffin inhibiting efficiencies of the paraffin inhibitors with the plurality of crude oils. Paraffin inhibiting efficiency is predicted based on the historical data set and extrapolated unknown properties for the plurality of paraffin inhibitors that may be used with the target crude oil. One or more of a list of crude oils having one or more properties within a numerical tolerance of the properties of the target crude oil, a list of paraffin inhibitors for use with the target crude oil, and a list of paraffin inhibitor properties are output.
A method can include receiving input for a multiwell pad; selecting, based at least in part on a portion of the input, a template for the multiwell pad; generating, based at least in part on the template, well trajectories for the multiwell pad, where each of the well trajectories extends from a surface location of the multiwell pad to one or more reservoir target locations and where each of the well trajectories includes at least one curve generated using one or more dogleg severity values and one or more geometric control points that are not required to lie on one or more of the well trajectories; and outputting specifications for the generated trajectories of the multiwell pad.
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
Alkali activated precursor compositions are presented that are useful for cementing a subterranean well, among other uses. The precursor compositions are dry mixtures that have an aluminosilicate source and an activator consisting of a metal carbonate, metal silicate, or combination thereof. A precursor is formed by adding water to the dry precursor compositions. Such precursors have suitable characteristics for use in cementing applications that use pumpable mixtures.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 28/00 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
A method for identifying a prospect in a subsurface formation includes receiving first data corresponding to one or more first subsurface formations. The method also includes training a machine learning (ML) model using the first data to produce a trained ML model. The method also includes receiving second data corresponding to one or more second subsurface formations. The method also includes identifying second prospects in the one or more second subsurface formations. The second prospects are identified using the trained ML model based upon the second data. The method also includes determining a chance of success in each of the second prospects using the trained ML model based upon the second data.
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
Systems and methods presented herein relate to techniques for modeling bridging and fluid diversion and generating a bridging volume output and/or fluid diversion output that indicates a bridging occurrence and/or operations to remedy the bridging. For example, a method includes utilizing a physics based empirical model to predict fluid diversion away from a constriction of a fluid diverter system based on an injection rate, concentration of diverter material, particulate type ratios of particulate types in the fluid diverter system, carrier fluid rheology, or a combination thereof. The method also includes generating an output based on the predicted fluid diversion.
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
Certain aspects of the disclosure are directed to methods for obtaining a drilling sequence. The method may include accessing data for actual and planned well trajectories; identifying potential collisions between the actual and planned well trajectories; adjusting the planned well trajectories to mitigate the identified potential collisions; and generating a drilling schedule based on the adjusted planned well trajectories.
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
E21B 41/00 - Equipment or details not covered by groups
74.
ML DRIVEN AUTOMATED SCREENING AND RANKING OF POTENTIAL CCS SITES
Disclosed are methods, systems, and computer programs that determine an optimal location for fluid storage operations at a first site (e.g., a carbon capture and storage (CCS) site). The methods include: determining first data for the first site; generating a trained first ML model using the first data; generating preliminary location data associated with the first site using the trained first model; receiving second data associated with the first site; generating a trained second ML model based on the second data; and determining optimal locations at the first site where fluid can be stored by applying to the trained second ML model, the preliminary location data associated with the first site.
A device may include a bit body with a rotational axis in a longitudinal direction. A device may include at least one blade coupled to the bit body with an outward surface. A device may include a rolling cutting element positioned on the outward surface. A device may include a fixed cutting element positioned with a fixed cutting profile at least partially rotationally overlapping with a rolling cutting profile of the rolling cutting element.
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
Systems and methods presented herein relate to real-time analysis of production chemicals at wellsites utilizing capillary electrophoresis (CE) analysis of produced water in-situ and in substantially real-time to determine the effectiveness and efficiency of production chemicals injected into wells. For example. systems and methods presented herein include CE equipment configured to receive sample fluids from production fluids extracted from various locations of wellsites, and to perform CE analysis to generate data relating to one or more fluid properties of the sample fluids. The systems and methods presented herein also include an analysis and control system configured to detect and quantify individual components of production chemicals injected into wells of the wellsites based at least in part on the data relating to the one or more fluid properties of the sample fluids.
Certain aspects of the present disclosure provide brine pre-treatment techniques for direct extraction. A method includes of recovering an element of interest from an aqueous source includes measuring one or more properties of a sample brine extracted from the aqueous source; comparing the measurements of the one or more properties of the sample brine to one or more specified thresholds or ranges; selecting one or more brine pre-treatment stages, of a plurality of configured brine pre-treatment stages, based on the comparison of the one or more properties of the sample brine to the one or more specified thresholds or ranges; and performing the selected one or more brine pre-treatment stages on a process brine extracted from the aqueous source.
C22B 3/24 - Treatment or purification of solutions, e.g. obtained by leaching by physical processes, e.g. by filtration, by magnetic means by adsorption on solid substances, e.g. by extraction with solid resins
Certain aspects of the present disclosure provide quantitative brine analysis techniques for mineral extraction. A method includes obtaining parameters of a sample brine extracted from the aqueous source; determining a brine pretreatment score based on one or more of the parameters of the sample brine; determining a brine extraction score based on one or more of the parameters of the sample brine; determining a brine post-extraction score based on one or more of the parameters of the sample brine; determining a brine total score based on the brine pretreatment score, the brine extraction score, and the brine post-extraction score; and outputting a visualization of at least one of: the brine pretreatment score, the brine extraction score, the brine post-extraction score, or the brine total score to a display.
Systems and methods of the present disclosure are configured to enable human annotators to quickly, and potentially in groups, annotate thousands of data points of content, so that each data point of content gets a value with respect to some attribute, so that data points of content showing more of the attribute have higher values than those showing less of the attribute. For example, a method includes presenting two content items of a plurality of content items via a user interface of a web-based application; receiving, via the user interface of a web-based application, an annotation relating to an indication of which of the two content items are associated with a criterion; and updating a score relating to the criterion for each of the plurality of content items based at last in part on the annotation.
A method includes receiving first input values for a first parameter of a physical system, calculating first modeled values for a second parameter using a model that represents the physical system, based on the first input values, receiving measured values for the second parameter, training a machine learning model to adjust modeled values generated by the model based on a difference between the first modeled values and the measured values, receiving second input values for the first parameter, calculating second modeled values for the second parameter using the model, generating adjusted values for the second parameter by adjusting the second modeled values using the trained machine learning model, and visualizing the adjusted values for the second parameter as representing operation of the physical system.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
A method for implementing enhanced oil recovery includes receiving a model of a subterranean volume of at least a portion of an oilfield and measurements collected for the subterranean volume, determining a model confidence index based at least in part on the model and the measurements, selecting one or more physical parameters for candidate pilot tests based at least in part on the model, the measurements, and the model confidence index, designing pilot tests for the individual candidate pilot tests based at least in part on one or more pilot test objectives, the model, and the model confidence index, selecting one or more pilot tests from among the designed pilot tests, and generating a pilot test implementation plan for the selected one or more pilot tests.
Embodiments presented provide for fracture geometry control of hydraulically created fractures in geological stratum. In embodiments, a stimulation well allows for activation of a geological stratum to be fractured, while monitoring activities are conducted by a monitoring well. Data from the monitoring well may be used in creating fracture geometry control of the stimulation well.
A method of selecting paraffin inhibitors for a target crude oil includes inputting one of more known properties of a target crude oil into a machine learning model and extrapolating unknown properties of a historical data set using a machine learning model. The machine learning model is trained on the historical data set that includes one or more properties of a plurality of crude oils, one or more properties of a plurality of paraffin inhibitors, and one or more paraffin inhibiting efficiencies of the paraffin inhibitors with the plurality of crude oils. Paraffin inhibiting efficiency is predicted based on the historical data set and extrapolated unknown properties for the plurality of paraffin inhibitors that may be used with the target crude oil. One or more of a list of crude oils having one or more properties within a numerical tolerance of the properties of the target crude oil, a list of paraffin inhibitors for use with the target crude oil, and a list of paraffin inhibitor properties are output.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
A method for determining insights about a drilling operation is disclosed. The method also includes generating a prediction for drilling a potential well in a formation in a subsurface based upon the first data and the second data. The method also includes generating a recommendation for drilling the potential well based upon the prediction. The recommendation includes surface coordinates for the potential well, a trajectory of the potential well, an azimuth of the potential well, a well design profile of the potential well, a drilling rig used to drill the potential well, a mud type pumped into the potential well, a bottom hole assembly (BHA) used to drill the potential well, a drill bit used to drill the potential well, or a weight on the drill bit.
Embodiments presented provide for a method for optimizing coiled tubing operations. In embodiments, a pre-job sensitivity analysis is coupled with real-time field measurements to arrive at a decision-making process to enhance the decision making.
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
E21B 41/00 - Equipment or details not covered by groups
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
Disclosed are methods, systems, and computer programs that determine stratigraphic marker data for energy development operations at a resource site. According to one embodiment, the methods include generating a stratigraphic model for the resource site. The stratigraphic model, for example, comprises a machine learning model having one or more parameters. The methods also include configuring the stratigraphic model using training data following which the trained stratigraphic model is used to generate, based on data captured at the resource site, stratigraphic marker data or geological facies data for the resource site. The stratigraphic marker data or geological facies data comprises geological sequence boundary data indicating uniform or non-uniform sediment deposition information or geological layering information associated with the resource site.
A system includes a first rotary steerable tool configured to control a first drilling bit to drill a first well having a first well path. The first rotary steerable tool includes a first direction and inclination component that includes a first set of sensors configured to detect a static magnetic field and a signal source configured to generate a source signal. The system also includes a second rotary steerable tool configured to control a second drilling bit to simultaneously drill a second well having a second well path that tracks the first well path. The second rotary steerable tool includes a second direction and inclination component that includes a second set of sensors configured to detect the source signal.
A technique facilitates deployment of open hole gravel packing equipment and sand control equipment downhole in a single trip. According to an embodiment, the technique utilizes a pipe string, e.g. a workstring or a drill string, for use in an open hole gravel packing operation. The pipe string is equipped with a sand control system having at least one filtration medium, Additionally, the pipe string comprises a valve and a valve actuation device. The valve actuation device is capable of being remotely activated in a manner allowing setting of one or more packers downhole without blocking subsequent flow through the pipe string.
A drilling fluid management system may measure drilling parameters for a downhole drilling system, the drilling parameters including standpipe pressure. A drilling fluid management system may determine, based on the drilling parameters, a mechanical specific energy (MSE). A drilling fluid management system may apply a changepoint model to the MSE and the standpipe pressure to identify a plurality of MSE segments and a plurality of pressure segments. A drilling fluid management system may identify an expected MSE and an expected pressure. A drilling fluid management system may identify an MSE segment having the segment MSE that differs from the expected MSE by an MSE threshold, and a pressure segment having the segment pressure that differs from the expected pressure by a pressure threshold. A drilling fluid management system may identify a lost-circulation period based on an overlap of the MSE segment and the pressure segment.
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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
90.
IMPLICIT STRUCTURAL MODELING USING TREE DATA STRUCTURES
A method includes receiving data representing a subsurface volume, the data including data points representing one or more physical properties of the subsurface volume, generating a tree data structure representing the subsurface volume, including partitioning a digital representation of the subsurface volume into mesh elements based at least in part on locations of the data points, storing a location of the mesh elements in the tree data structure, and assigning coefficients to the mesh elements, the coefficients representing one or more physical properties of the subsurface volume represented by the individual mesh elements. The method also includes determining an implicit function representing the one or more physical properties of the subsurface volume based at least in part on the assigned coefficients, the implicit function being continuous across a domain, and visualizing at least a portion of the subsurface volume based at least in part on the implicit function.
A digital twin generator may receive a model for the physical asset, the model including one or more bound parameters and one or more static parameters associated with the model. A digital twin generator may bind the one or more bound parameters to historical sensor data from a sensor at the physical asset. A digital twin generator may receive a physical measurement from the sensor at the physical asset, the physical measurement including an update to the historical sensor data. A digital twin generator may generate an updated model including the one or more updated bound parameters and the one or more static parameters.
A method for suppressing noise in seismic data includes receiving input seismic data. The method also includes extracting attributes from the input seismic data. The attributes are used to characterize coherent noise in the seismic data. The method also includes identifying noise suppression parameters based upon the attributes. The method also includes applying the noise suppression parameters to the input seismic data to produce output seismic data.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
E21B 47/14 - 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 using acoustic waves
93.
METHOD TO DEVELOP COMPUTER AIDED ENGINEERING MODELS IN HYDROCARBON RECOVERY PROJECTS AND INDUSTRY
Embodiments presented provide for a system that provides calculation for components used in hydrocarbon recovery projects. Arrays of size ranges for components are provided for selection to a designer based on loading conditions expected.
A cleaning cutting element includes an ultrahard layer joined to a substrate. The substrate includes a substrate bore formed at least partially therethrough. The substrate includes a plurality of conduits that extend from the substrate bore at a junction. The conduits exit the substrate at an exit opening in the circumferential wall to direct drilling fluid to a feature of the bit to which the cleaning cutting element is secured.
A method for validating a well test includes receiving historical well test data. The historical well test data includes one or more accepted flags and one or more rejected flags. The method also includes training a machine-learning (ML) model based upon the historical well test data to produce a trained ML model. The method also includes receiving new well test data. The new well test data does not include the one or more accepted flags and the one or more rejected flags. The method also includes determining whether the new well test data meets or exceeds a predetermined validation threshold using the trained ML model.
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 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
Systems and methods presented herein utilize text mining, Optical Character Recognition (OCR), Natural Language Processing (NLP), and Named Entity Recognition (NER) to extract entity relations for spatial exploration and production (E&P) objects and document categories from unstructured document content autonomously. Language models may be utilized and the results between them may be compared. The extracted information may then be linked to a structured database that contains geolocations.
G06F 16/387 - Retrieval characterised by using metadata, e.g. metadata not derived from the content or metadata generated manually using geographical or spatial information, e.g. location
POLYMER-BASED ADDITIVES FOR SHALE STABILIZATIONS, WELLBORE FLUID COMPOSITIONS COMPRISING SAID ADDITIVES, AND METHODS OF PRODUCING SAID COMPOSITIONS AND IMPROVING SHALE STABILIZATIONS USING SAID COMPOSITIONS
Polymer-based additives improve shale stabilizations by being incorporated into wellbore fluid compositions for one or more wellbore operations or applications. Methods of producing said compositions and using said compositions to stabilize shale associated with wellbores disposed within subterranean formations are also provided. Wellbore fluid compositions comprising aqueous base fluids and the polymer-based additives and methods of introducing or circulating said compositions into the wellbores for stabilizing shales associated the wellbores are further provided.
23030 hydrocarbon radical bonded to one of the nitrogen atoms of the heterocyclic diamine. Relative methods of operating a wellbore and breaker fluid compositions are also disclosed.
Embodiments presented provide for a method for calculating emissions for hydrocarbon recovery operations. In embodiments, databases for equipment and activities are accessed to estimate equivalent greenhouse gas emissions for anticipated wellbore activities.
E21B 41/00 - Equipment or details not covered by groups
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
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POLYMER-BASED ADDITIVES FOR SHALE STABILIZATIONS, WELLBORE FLUID COMPOSITIONS COMPRISING SAID ADDITIVES, AND METHODS OF PRODUCING SAID COMPOSITIONS AND IMPROVING SHALE STABILIZATIONS USING SAID COMPOSITIONS
Polymer-based additives improve shale stabilizations by being incorporated into wellbore fluid compositions for one or more wellbore operations or applications. Methods of producing said compositions and using said compositions to stabilize shale associated with wellbores disposed within subterranean formations are also provided. Wellbore fluid compositions comprising aqueous base fluids and the polymer-based additives and methods of introducing or circulating said compositions into the wellbores for stabilizing shales associated the wellbores are further provided.
