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
2.
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
3.
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.
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
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
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
7.
IMPROVED 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
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
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.
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
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
13.
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
14.
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
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
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
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.
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
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.
E21B 10/60 - Drill bits characterised by conduits or nozzles for drilling fluids
E21B 10/48 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of core type
21.
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.
Embodiments presented provide for an automated method for data input for the hydrocarbon recovery industry. In certain embodiments, data from steps before completion of a wellbore is retained and input into completion software, alleviating the need for manual data retention.
A subsurface hydraulic energy storage system includes a reservoir configured to store a downhole fluid, a turbine coupled to a generator, and an electrical submersible pump (ESP) installed at a target depth in a wellbore in a geological formation. Geothermal heat from the downhole fluid is configured to drive the turbine and the generator, and the generator is electrically connected to an electrical network. The ESP is electrically connected to a power control system electrically connected to the electrical network. The ESP is in fluid communication with the reservoir, and the ESP is configured in an active mode to utilize electrical power from the electrical network to pump the downhole fluid having the geothermal heat from the geological formation to the reservoir.
A method for deploying a pump in a well includes attaching a well closure device above a surface control valve, wherein the surface control valve is connected to close a well tubing extending from the well control valve to a predetermined depth in the well. An annular seal and downhole control valve are moved to a selected pump setting depth in the well tubing. The downhole control valve is operable to close the well tubing to fluid flow. The pump is extended into the well tubing at the end of an electrical cable through the well closure device and the well tubing until the pump engages the downhole control valve or the annular seal. The electrical cable is terminated at its surface end with a well penetrator such that the well penetrator seats in the well closure device.
The invention relates to a unit (200) for producing hydrogen that comprises: - a stack (102) of solid oxide cells, - an air circuit (110), and a fuel circuit (120) passing through the stack (102); characterised in that the unit (200) is equipped with a stopping system comprising: - an inlet (202) and an outlet (204) for neutral gas, for circulating a predetermined neutral gas in the stack; - an inlet (206) and an outlet (208) for safety gas, for circulating a safety gas in the stack (102); and - a control module (210) for switching the stack (102) from the production configuration to the stopped configuration. The invention also relates to a method for controlling such a unit.
A drilling fluid for drilling a subterranean wellbore includes water and a viscosifier including a crosslinked polymer comprising a polymer formed from one or more monomers, and a crosslinker comprising a reaction product of a first reactant including a linear amine and a second reactant including an ether including an epoxide group. Related methods of operating a wellbore and drilling fluids are disclosed.
A well testing package is coupled to a well. A first fluid is produced from a first production zone of the well to the well testing package. The first fluid is returned to the well from the well testing package, and is injected into a second production zone of the well.
Systems and methods provide a bottom hole assembly for a wellbore that includes a drill bit and multiple drilling tools. The multiple drilling tools include multiple sensors configured to capture a multiple instances of a common measurement type at multiple locations along a drill string. The multiple drilling tools also include processing circuitry configured to compare the multiple instances of the common measurement type to determine a difference among the multiple instances. The processing circuitry is also configured to determine that the difference is greater than a threshold corresponding to an inference of high frequency torsional oscillation. Furthermore, the processing circuitry is further configured to send an indication of an occurrence of high frequency torsional oscillation in the bottom hole assembly.
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
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
Embodiments presented provide for an optimization approach for production metering. The optimization approach uses a stability evaluation with data sets to provide for accurate decision making by a user. The method can include using filtering of periodical components of data to create remaining data if the data of the metering operation is quasi-periodic.
Embodiments presented provide for a system and method for automating the monitoring of a large population of field systems. The recovery of data pertaining to each of the field systems may be used in structural health monitoring to increase project safety, improve maintenance of the facilities, and increase economic returns.
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
The invention relates to a method for producing hydrogen that comprises the following steps: - high-temperature electrolysis of steam in an electrolysis unit (102) taking as input a first flow (F1) comprising steam and a second flow (F2) comprising air, the electrolysis providing a third flow (F3) comprising hydrogen and nitrogen; and - separating the hydrogen and the nitrogen in the third flow (F3), in a purification unit (110), provided to receive the third flow (F3) and provide a fourth flow (F4) essentially comprising hydrogen, and a fifth flow (F5) comprising hydrogen and nitrogen; characterised in that the method further comprises recovering the hydrogen contained in the fifth flow (F5) for the electrolysis. The invention also relates to a system (300) implementing such a method.
C25B 1/042 - Hydrogen or oxygen by electrolysis of water by electrolysis of steam
H01M 8/12 - Fuel cells with solid electrolytes operating at high temperature, e.g. with stabilised ZrO2 electrolyte
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
C25B 15/08 - Supplying or removing reactants or electrolytesRegeneration of electrolytes
A method for estimating EM measurement uncertainty includes evaluating EM logging measurements with a trained machine learning model to estimate the measurement uncertainties of the EM logging measurements. The trained machine learning model is trained using a training data set made up of modeled EM logging measurements and corresponding measurement uncertainties.
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 47/13 - 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
A method may plate a Nickel (Ni)-plating layer on a radially outward surface of a carbide substrate of a cutting element to create a Ni-plated carbide substrate. A method may braze the Ni-plated carbide substrate to a cutting element pocket of the drill bit.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
B23P 15/28 - Making specific metal objects by operations not covered by a single other subclass or a group in this subclass cutting tools
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
A downhole tool is provided with a neutron generator configured to emit neutrons into a geological formation. The downhole tool includes one or more neutron detectors configured to detect neutrons that return to the downhole tool after interacting with the geological formation. The downhole tool also includes one or more gamma ray detectors configured to detect gamma rays from the geological formation that form when neutrons are inelastically scattered by the geological formation. Measurements from a combination of detectors of at least one of the one or more neutron detectors and at least one of the one or more gamma ray detectors are used to determine formation density. A first formation density determined using a first combination of detectors is used to compensate a second formation density determined using a second combination of detectors.
G01V 5/10 - 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 neutron sources
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
37.
STIMULATION JOB DESIGN AND EXECUTION ADVISORS FOR OPTIMAL FRACTURE PERFORMANCE
Systems and methods presented herein enable stimulation job design and execution advisors for optimal fracture performance. For example, a control system may include one or more processors configured to execute processor-executable instructions stored on memory of the control system, wherein the processor-executable instructions, when executed by the one or more processors, cause the control system to initiate and implement one or more software modules in a modular manner to optimize parameters of a hydraulic stimulation job, and to provide advice regarding one or more adjustments to the parameters of the hydraulic stimulation job in substantially real-time during performance of the hydraulic stimulation job.
Systems and methods presented herein enable stimulation job design and execution advisors for optimal fracture performance. For example, a control system may include one or more processors configured to execute processor-executable instructions stored on memory of the control system, wherein the processor-executable instructions, when executed by the one or more processors, cause the control system to initiate and implement one or more software modules in a modular manner to optimize parameters of a hydraulic stimulation job, and to provide advice regarding one or more adjustments to the parameters of the hydraulic stimulation job in substantially real-time during performance of the hydraulic stimulation job.
Embodiments presented provide for a method for carbon capture. Carbon dioxide is obtained from an industrial, carbon dioxide, generator and then effectively used as feedstock for a carbon dioxide use facility or is sequestered at a wellhead until use is required as a feedstock at a later time.
E21B 41/00 - Equipment or details not covered by groups
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
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
40.
A METHOD TO REDUCE CARBON DIOXIDE RECOVERY FROM SUBSURFACE LOCATIONS
Embodiments presented provide for a method for effectively utilizing carbon dioxide in hydrocarbon recovery operations. In embodiments, a system is used to increase residual carbon dioxide saturation and increase carbon dioxide recovery for wellbore applications.
Embodiments presented provide for a method to decarbonize hydrocarbon recovery operations. Decarbonization occurs through modifications made to geological stratum to encourage carbon dioxide capture and with holding capabilities. A method for carbon dioxide sequestration in a wellsite located within the geological stratum, comprises: calculating sealing efficiency of the geological stratum for which the carbon dioxide will be stored; evaluating relative permeability behavior of the carbon dioxide for the geological stratum; performing a numerical modeling of a reservoir and the geological stratum for at least one of a hydraulic fracturing of the wellsite, a stimulation of the wellsite, and an intervention of the wellsite; obtaining results that are optimized from the numerical modeling; and based upon the results from the optimized numerical modeling, conducting with the carbon dioxide, at least one of the hydraulic fracturing of the wellsite, the stimulation of the wellsite, and the intervention of the wellsite.
Methods and apparatus for treating water are described herein. A method of treating water having unwanted materials includes pretreating a water stream having unwanted materials to form pretreated water; and routing the pretreated water to a dead-end ionic filter unit comprising a housing, a flow barrier disposed in an interior of the housing between an inlet and an outlet of the housing, a plurality of filter elements coupled to the flow barrier in the interior of the housing to define flow pathways within the housing through the flow barrier from an inlet side of the housing to an outlet side of the housing, and an ionic filter material disposed in the interior of the housing at the inlet side.
In some embodiments, a process can include obtaining a first formation fluid sample using a sample-line of a focused fluid sampling system and obtaining a second formation fluid sample using a guard-line of the focused fluid sampling system. The process can also include measuring a first optical density spectrum of the first formation fluid sample and measuring a second optical density spectrum of the second formation fluid sample. The process can also include decolorizing the first and second optical density spectrums to produce a decolorized first spectrum and a decolorized second spectrum, respectively. The process can also include normalizing the first and second decolorized spectrums to provide a first normalized spectrum and a second normalized spectrum. The process can also include determining a difference between the first and the second normalized spectrums to provide a sampling difference and adjusting a fluid sampling operation based on the sampling difference.
Well spacer materials containing geopolymer adjuvants that polymerize under alkaline conditions are used to precede pumping geopolymer precursors into a well. Use of geopolymer adjuvant in the spacer material reduces hardening loss in the geopolymer at the interface with the spacer material. The geopolymer adjuvant can partially or entirely replace conventional weighting materials used in spacer compositions.
A thermal system includes a borehole heat exchanger, a facility having a peak heating load, a data center including at least one heat generating electronic component, and a ground-source heat pump. The data center, the borehole heat exchanger, and the ground-source heat pump are connected in a dynamic downhole fluid circuit with a flow of a downhole fluid. The dynamic downhole fluid circuit is configured to reject heat from the data center to the facility and to the BHE, and a power capacity of the data center is less than the peak heating load of the facility.
The disclosed techniques relate to fluid monitoring and classification techniques that include a method that includes acquiring, via a spectral analysis module of a sampling system of a downhole well tool, spectral data for an unknown reservoir fluid received by the sampling system of the downhole well tool from a geological formation; determining, via the one or more processors, a fluid type of the unknown reservoir fluid in the sampling system of the downhole well tool based at least in part on projections of the spectral data for the unknown reservoir fluid onto at least the first two eigenvectors of spectral data of known fluids stored in a spectral database; and generating, via the one or more processors, a downhole well operation decision based on the determined fluid type of the unknown reservoir fluid in substantially real-time while the sampling system of the downhole well tool receives the unknown reservoir fluid.
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
47.
GROUND-SOURCE THERMAL SYSTEM FOR REJECTING DATA CENTER WASTE HEAT TO A FACILITY
A thermal system (100) includes a borehole heat exchanger (112), a facility (122), a data center (114) including at least one heat generating electronic component, and a ground-source heat pump (116). A dynamic downhole fluid circuit (110) connects the data center (114), the borehole heat exchanger (112), and the ground-source heat pump (116) with a flow of a downhole fluid and is configured to connect the data center (114), the borehole heat exchanger (112), and the ground-source heat pump (116) in a plurality of different configurations to reject heat from the data center (114). The thermal system further includes a facility fluid circuit (124) for connecting the facility (122) and the ground-source heat pump (116) with a facility fluid, wherein the ground-source heat pump (116) thermally connects the dynamic downhole fluid circuit (110) and the facility fluid circuit (120).
A heat transfer device, such as a heat exchanger, has dimensions and flow speed such that Reynolds number for the flow is in a range from 1 to 1000. The device uses a working fluid which is in a state of elastic turbulence. This enhances transfer of heat to or from the working fluid. In some embodiments the fluid is an emulsion with a disperse phase which changes between liquid and solid so that its latent heat of fusion contributes to the amount of heat carried by the working fluid.
F24S 80/20 - Working fluids specially adapted for solar heat collectors
F24S 10/75 - Solar heat collectors using working fluids the working fluids being conveyed through tubular absorbing conduits with enlarged surfaces, e.g. with protrusions or corrugations
F24S 70/60 - Details of absorbing elements characterised by the structure or construction
F28F 13/12 - Arrangements for modifying heat transfer, e.g. increasing, decreasing by affecting the pattern of flow of the heat-exchange media by creating turbulence, e.g. by stirring, by increasing the force of circulation
A cement composition for a subterranean wellbore includes at least one cement binder, at least one compressive strength additive, and a density reducing material. The at least one compressive strength additive constitutes between about 0.1 weight percent and about 20 weight percent of the cement composition and the density reducing material constitutes between about 1 weight percent and about 40 weight percent of a density reducing material. Related cement slurry compositions and methods are also disclosed.
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
C09K 8/473 - Density reducing additives, e.g. for obtaining foamed cement compositions
E21B 33/13 - Methods or devices for cementing, for plugging holes, crevices or the like
A thermal system for a facility includes a facility fluid circuit, a ground-source heat pump, and an air-source heat pump. The ground-source heat pump and the air-source heat pump each include a fluid circuit connected to the facility fluid circuit in parallel via a common facility heat exchanger. The ground-source heat pump includes a ground-source heat exchanger for transferring heat between a ground-source working fluid and a downhole fluid of a downhole fluid circuit. The air-source heat pump includes an air-source heat exchanger for transferring heat between an air-source working fluid and an ambient air. Heat can be transferred, at the facility heat exchanger, between the facility fluid and one or more of the ground-source working fluid or the air-source working fluid in order to provide thermal heating, cooling, or both to the facility.
A control unit may obtain a drill plan. A control unit may receive status information from a measurement while drilling (MWD) unit in data communication with the control unit. A control unit may determine, based on the status information and the drill plan, at least one actuation timing of a biasing element. A control unit may actuate at least one biasing element of a directional steering tool based on the actuation timing.
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 41/00 - Equipment or details not covered by groups
52.
SYSTEMS AND METHODS FOR INFERRING RESERVOIR PRESSURE BASED ON INITIAL COILED TUBING RUN CONDITIONS
Systems and methods presented herein facilitate coiled tubing operations, and generally relate to automatically improving performance of coiled tubing operations in substantially real time by inferring reservoir pressure based on initial coiled tubing run conditions. For example, a method includes performing a coiled tubing operation via a coiled tubing system at least partially disposed within a wellbore. The method also includes detecting data relating to operating parameters of the coiled tubing operation via sensors of the coiled tubing system during the coiled tubing operation. The method further includes determining an initial wellbore fluid distribution in the wellbore based on the detected data prior to pumping fluid into the wellbore from a surface location relative to the wellbore. In addition, the method includes inferring a reservoir pressure of a hydrocarbon-bearing reservoir through which the wellbore extends based on the initial wellbore fluid distribution in the wellbore.
Certain embodiments of the present disclosure include methods, systems, and apparatus for automatically generating a pull test schedule and/or executing one or more pull tests. In certain embodiments, a priori data may be used to automatically generate a pull test plan or schedule. In addition, in certain embodiments, real-time data may be used to automatically and/or manually adjust or fine-tune the pull test schedule. In addition, in certain embodiments, an application may automatically generate a pull test schedule and/or automate one or more pull tests. In addition, in certain embodiments, the application may automatically advise a coiled tubing (CT) operator regarding where and how to pull test in substantially real-time.
An electrochemical cell wherein electrolyte flows through the cell, as in a redox flow battery or a fuel cell, uses electrolyte(s) which are in a state of elastic turbulence in contact with the electrode(s). The elastic turbulence enhances transport of electrochemically reactive species to the surfaces of the electrode(s) and the transport of reaction products away from those surfaces.
H01M 8/18 - Regenerative fuel cells, e.g. redox flow batteries or secondary fuel cells
H01M 8/0258 - CollectorsSeparators, e.g. bipolar separatorsInterconnectors characterised by the configuration of channels, e.g. by the flow field of the reactant or coolant
H01M 8/04186 - Arrangements for control of reactant parameters, e.g. pressure or concentration of liquid-charged or electrolyte-charged reactants
H01M 8/04082 - Arrangements for control of reactant parameters, e.g. pressure or concentration
H01M 4/86 - Inert electrodes with catalytic activity, e.g. for fuel cells
A fluid composition which is able to exhibit elastic turbulence while pumped through a flow path which compels changes of direction of flow streamlines and comprise a solution of two or more flexible linear polymers in two categories. The first category has an average molecular weight of at least 10 MegaDaltons and the second category has an average molecular weight in a range from 0.25 to 5 MegaDaltons. The concentration of the first polymer is sufficient to enable elastic turbulence with or without the second category. The concentration of the second category is greater than that of the first. When flowing under low shear towards or away from a chamber where the flow path will induce elastic turbulence, the second category polymer reduces elastic instabilities and consequent pressure drop, thereby reducing pumping energy requirement.
The present disclosure generally provides systems and methods and apparatuses for filtering an inflowing formation fluid. In some embodiments, a screen assembly for use within a wellbore includes a base pipe comprising a plurality of holes disposed therein and a filter disposed within one of the plurality of holes. The filter includes a filter disk and an elastomeric seal having a circular cross-sectional area. The screen assembly further includes a plurality of axial wires disposed over the outer surface of the base pipe, and a plurality of wrap wires perpendicularly disposed over the periphery of the plurality of axial wires.
A thermal system for providing thermal conditioning to a facility includes a facility air circuit for circulating a facility air throughout the facility and a downhole fluid circuit for circulating a downhole fluid. The facility air circuit is thermally connected to a heat pump for exchanging heat with the facility air. The downhole fluid circuit includes the heat pump for exchanging heat with the downhole fluid, a main loop, including a borehole heat exchanger (BHE) for exchanging heat between the downhole fluid and a geological formation, and an exhaust loop including an exhaust heat exchanger coupled to an exhaust of the facility air circuit, wherein the exhaust loop is configured to circulate at least some of the downhole fluid through the exhaust heat exchanger to exchange heat between the downhole fluid and an exhaust flow of the facility air exhausted from the facility at the exhaust.
A method for evaluating a multiphase oilfield fluid includes blending a first sample of the fluid with a viscosity modifying agent to transform the sample into a paste; making a first XRF measurement of the paste to estimate an elemental composition of the fluid; making a calcimetry measurement of a second sample of the fluid to estimate a total carbonate concentration of the fluid and to obtain an acidified second sample; separating the acidified second sample to obtain an acidified brine; making a second XRF measurement of the acidified brine to estimate an elemental composition of the acidified brine; and determining an elemental composition of a solid phase of the multiphase oilfield fluid from the elemental composition of the acidified brine and the elemental composition of the multiphase oilfield fluid.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 23/223 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by measuring secondary emission from the material by irradiating the sample with X-rays or gamma-rays and by measuring X-ray fluorescence
Geopolymer precursors are presented that are useful for subterranean wells. Methods include forming a geopolymer precursor comprising an aluminosilicate source, an activator and a carrier fluid having a soluble density modifier; placing the geopolymer precursor into a subterranean well; and causing the geopolymer precursor to set within the subterranean well to form a geopolymer. Related geopolymer precursor composition, comprising an alkali-reactive aluminum-, silicon-, and oxygen-containing material, an activator and a carrier fluid having a soluble density modifier are also disclosed.
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 generating synthetic sensor data during a drill operation includes training an artificial intelligence based backup sensor model, deploying the trained backup sensor model at a drilling location, and evaluating sensor data acquired from a plurality of sensors while drilling with the trained backup sensor model to synthesize backup sensor data.
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 5/12 - 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
A system may obtain one or more samples of an analysis fluid obtained at a predetermined location and containing a target fluid and a drilling fluid, wherein the drilling fluid has a known initial composition. A system may place the one or more samples into a capillary electrophoresis device. A system may determine a concentration of at least a target ion in the target fluid of the one or more samples using the capillary electrophoresis device. A system may evaluate at least a criterion relative to an extraction plan for extracting the target ion at the location based on the determined concentration.
A device may include a needle having a taper surface toward a distal end and a proximal portion opposite the distal end in an axial direction, wherein a surface of the needle includes polycrystalline diamond. A device may include a base including a non-diamond material positioned around the proximal portion, wherein the base is joined to the proximal portion of the needle by a compression fit.
A porous structural thermoset media is described herein. A method includes compressing a porous structural thermoset material having a first diameter to a second diameter that is smaller than the first diameter. The method also includes adding a containment material to the porous structural thermoset material, wherein the containment material provides a mechanical force to restrict expansion of the porous structural thermoset material in a radial direction.
A method of reducing corrosion within a wellbore includes placing a wireline including a perforating gun in a wellbore, the wellbore extending through an earth formation and including a casing extending through the earth formation, the wireline including zinc, discharging the perforating gun to form perforations through the casing and in the earth formation surrounding the casing proximate the at least one perforating gun, flowing a fracturing fluid including one or more proppants through the perforations and into the earth formation to open fractures in the earth formation with the one or more proppants, introducing a flushing fluid into the wellbore to displace the fracturing fluid, and flowing a corrosion inhibitor composition into the wellbore and through the perforations with at least one of the fracturing fluid and the flushing fluid. The corrosion inhibitor includes an alkenylphenone, and a substituted 1-azanapthalene. Related methods of inhibiting corrosion are also disclosed.
A structural thermoset media, processes, and compositions are described herein. A method includes providing one or more monomers and one or more catalysts to form a thermoset composition. The method also includes generating an elastomeric material using the one or more monomers and the one or more catalysts. Further, the method includes generating an elastomeric material based on a reaction between the one or more catalysts and the one or more monomer units. The elastomeric material has a first crosslink density between about 40% and 80%. The first crosslink density of the elastomeric material is configured to increase to a second crosslink density when subjected to downhole conditions to generate a structural thermoset material. The second crosslink density is greater than or equal to about 95%.
C08J 9/26 - Working-up of macromolecular substances to porous or cellular articles or materialsAfter-treatment thereof by elimination of a solid phase from a macromolecular composition or article, e.g. leaching out
C08F 32/08 - Homopolymers or copolymers of cyclic compounds having no unsaturated aliphatic radicals in a side chain, and having one or more carbon-to-carbon double bonds in a carbocyclic ring system having condensed rings
C08F 232/08 - Copolymers of cyclic compounds containing no unsaturated aliphatic radicals in a side chain, and having one or more carbon-to-carbon double bonds in a carbocyclic ring system having condensed rings
C08F 2/44 - Polymerisation in the presence of compounding ingredients, e.g. plasticisers, dyestuffs, fillers
C08G 61/08 - Macromolecular compounds containing only carbon atoms in the main chain of the macromolecule, e.g. polyxylylenes only aliphatic carbon atoms prepared by ring-opening of carbocyclic compounds of carbocyclic compounds containing one or more carbon-to-carbon double bonds in the ring
A carbon dioxide injection manager may pump carbon dioxide into a wellbore with a carbon dioxide pump. A carbon dioxide injection manager may measure a carbon dioxide temperature of the carbon dioxide at the wellbore. A carbon dioxide injection manager may, based on the carbon dioxide temperature, increase a temperature of the carbon dioxide between the carbon dioxide pump and the wellbore.
A method for automatically determining an NMR pulse sequence for use in downhole NMR measurements, such as NMR logging while drilling measurements, includes receiving a set of expected NMR measurements and evaluating the received set of expected NMR measurements using a bilevel optimization to determine a pulse sequence for the downhole NMR measurement.
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
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
68.
RATE OF PENETRATION FORECASTING WHILE DRILLING USING A TRANSFORMER-BASED DEEP LEARNING MODEL
A method for forecasting a rate of penetration while drilling includes training a transformer-based machine learning model with historical drilling data obtained from a plurality of drilled wells to establish relationships between measured drilling parameters and ROP; acquiring short context drilling data while drilling the subterranean wellbore, the short context drilling data including a plurality of measured drilling parameters and a corresponding ROP; evaluating the short context drilling data using the trained transformer-based machine learning model to update the relationships between the measured drilling parameters and the ROP; and forecasting a future ROP using the short context drilling data and the updated relationships.
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
B01J 20/20 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising free carbonSolid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising inorganic material comprising carbon obtained by carbonising processes
B01J 20/22 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising organic material
B01J 20/30 - Processes for preparing, regenerating or reactivating
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
70.
METHODS OF CAPTURING CARBON DIOXIDE FROM A FLUE GAS, AND RELATED SYSTEMS
A method of capturing carbon dioxide from a flue gas includes flowing a flue gas including carbon dioxide through a first region of a sorbent bed, to a second region of the sorbent bed, and through the second region of the sorbent bed to adsorb carbon dioxide on sorbent within the first region and the second region, desorbing the carbon dioxide from the sorbent in the first region to generate a first carbon dioxide-rich gas, and desorbing the carbon dioxide from the sorbent in the second region to generate a second carbon dioxide-rich gas having a lower concentration of carbon dioxide than the first carbon dioxide-rich gas. Related carbon capture systems and integrated combustion and carbon capture systems are also disclosed.
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
71.
SMART DATA ACQUISITION FOR GYROCOMPASS APPLICATIONS
A method for making gyroscopic azimuth measurements includes estimating a pitch angle and a roll angle of a gyroscopic surveying tool in a wellbore; determining a measurement duration for each of a plurality of gyroscope measurements from the estimated pitch and roll angles; making each of the plurality of gyroscope measurements at the determined measurement duration when the gyroscope is disposed at a corresponding plurality of rotational positions in the tool housing; and computing an azimuth of the wellbore from the plurality of gyroscope measurements.
E21B 47/022 - Determining slope or direction of the borehole, e.g. using geomagnetism
G01C 19/38 - Rotary gyroscopes for indicating a direction in the horizontal plane, e.g. directional gyroscopes with north-seeking action by other than magnetic means, e.g. gyrocompasses using earth's rotation
72.
BLOWOUT PREVENTER SYSTEM AND METHOD UTILIZING SHEAR RAM BUTTRESS
A technique facilitates reliable operation of a blowout preventer (BOP) system. The reliable operation is achieved by utilizing a ram with improved strength so as to make it better able to resist the stresses from shearing without increasing the thickness of the ram blade. As a result, a high level of efficiency is maintained during a shearing action. According to an embodiment, a blowout preventer system comprises a blowout preventer shear ram assembly having a ram for shearing a tubular member. The ram comprises a main body and a blade extending from the main body. Additionally, a ramp buttress is secured to the blade to strengthen the blade and to improve the shearing action.
Methods for reducing fluid loss in subterranean wells are presented herein. The methods generally include contacting a brine with an alkali metal silicate within a subterranean formation, and applying a sealant to the formation. In one method, a brine solution is pumped into a well, an alkali metal silicate solution is pumped into the well in contact with the brine solution, a sealant is pumped into the well after the alkali metal silicate solution to restrict flow pathways within the formation, and the sealant is displaced from the well into the formation. The brine is allowed to react with the alkali metal silicate to precipitate solids that enhance the sealing performance of the sealant and further restrict the flow pathways within the formation
E21B 33/138 - Plastering the borehole wallInjecting into the formation
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
C04B 22/00 - Use of inorganic materials as active ingredients for mortars, concrete or artificial stone, e.g. accelerators
C04B 28/24 - 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 containing alkyl ammonium or alkali metal silicatesCompositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements containing silica sols
C04B 103/46 - Water-loss reducers, hygroscopic or hydrophilic agents
C04B 111/00 - Function, property or use of the mortars, concrete or artificial stone
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 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.
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
78.
METHOD FOR DE-RISKING RESERVOIR ARCHITECTURE THROUGH SIMULATION OF FLUID CHARGE
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
83.
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
89.
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
90.
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
91.
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
92.
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
