Continuous monitoring of density in lithium extraction and recovery using inertial density sensors is described herein. Lithium recovery methods and processes using inertial density sensors are also described herein. A method comprises detecting a first density of an aqueous material using an inertial density sensor; performing an operation on the aqueous material to change a lithium concentration of the aqueous material; after performing the operation, detecting a second density of the aqueous material using an inertial density sensor; comparing the first density with the second density; and determining a change in concentration of lithium in the aqueous material based on the comparison.
B01D 15/10 - Selective adsorption, e.g. chromatography characterised by constructional or operational features
B01D 15/20 - Selective adsorption, e.g. chromatography characterised by constructional or operational features relating to the conditioning of the sorbent material
B01D 15/42 - Selective adsorption, e.g. chromatography characterised by the development mode, e.g. by displacement or by elution
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
G01F 1/84 - Coriolis or gyroscopic mass flowmeters
G01N 9/32 - Investigating density or specific gravity of materialsAnalysing materials by determining density or specific gravity by using flow properties of fluids, e.g. flow through tubes or apertures
Latch designs for downhole components are provided. Some latch designs automatically lock in place in a mandrel pocket, for example automatically lock on or relative to both the no-go up and no-go down shoulders of the mandrel, when set. The latch designs reduce the range of movement of the latch within the mandrel pocket.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 23/02 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for locking the tools or the like in landing nipples or in recesses between adjacent sections of tubing
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
3.
AUTOMATED WORKFLOW TO OPTIMIZE PARAMETERS FOR FORMATION PRESSURE MEASUREMENTS UTILIZING MEMOIZATION
The disclosed methods include: determining distribution data for a subsurface environment of interest; generating, based on the distribution data, a set of test scenarios; combining, based on the distribution data and a first test scenario comprised in the set of test scenarios, a first combination of fluid rate data and fluid volume data; combining, based on the distribution data and a second test scenario comprised in the set of test scenarios, a second combination of fluid rate data and fluid volume data; generating, based on the first combination of fluid rate data and fluid volume data, a first pressure curve; generating, based on the second combination of fluid rate data and fluid volume data, a second pressure curve; determining, based on the first pressure curve or the second pressure curve, convergence data; generating, based on the convergence data, optimal data values for configuring energy exploration equipment.
Methods and compositions for treating a siliceous geologic formation are described herein. An aqueous treatment composition for treating such formations includes an acid having molecular weight less than about 200, or an ammonium or sodium salt thereof, an HF source, and from about 0.1 wt % to about 2.0 wt % of a fluoride scale inhibitor, the aqueous treatment composition having a pH from about 1.0 to about 3.0.
Systems and methods presented herein include systems and methods for receiving data relating to an injection/falloff test performed in a well in fluid communication with a subterranean reservoir; determining operational parameters of a hydraulic fracturing operation using at least a portion of the data; applying the operational parameters to a pre-trained machine learning predictive model to determine an optimal set of control parameters; and issuing one or more commands relating to the control parameters to optimize the hydraulic fracturing operation on the subterranean reservoir.
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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
6.
FLUID SEALING FOR DOWNHOLE ACOUSTIC MEASUREMENT TOOL
A fluid seal assembly having a sleeve disposed circumferentially around a downhole tool. First and second fasteners extend circumferentially around the sleeve proximate respective first and second ends of the sleeve. The first and second fasteners may comprise a shape-memory alloy that, in response to a temporarily increased temperature, have caused the first and second fasteners to circumferentially compress the sleeve against an outer surface of the downhole tool.
Methods include pumping a fracturing pad fluid into a subterranean formation under conditions of sufficient rate and pressure to create at least one fracture in the subterranean formation, the fracturing pad fluid including a carrier fluid and a plurality of bridging particles, the bridging particles forming a bridge in a fracture tip of a far field region of the formation. Methods further include pumping a first plurality of fibers into the subterranean formation to form a low permeability plug with the bridging particles, and pumping a proppant fluid comprising a plurality of proppant particles.
C09K 8/516 - Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/504 - Compositions based on water or polar solvents
C09K 8/508 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
C09K 8/514 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
C09K 8/80 - Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
E21B 33/138 - Plastering the borehole wallInjecting into the formation
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
Processes for determining dolomitization and reservoir rock quality and processes for using the same are provided. In some embodiments, the process can include determining an average acoustic pore aspect ratio of a formation from an acoustic log of the formation; determining one or more nuclear magnetic resonance (NMR) rock types of the formation from an NMR log of the formation; combining the average acoustic pore aspect ratio and the one or more NMR rock types to determine one or more preferred formation locations; and directing an operational plan for one or more wells using the one or more preferred formation locations.
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 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
9.
AUTOMATIC REPEATABILITY ENFORCEMENT FOR TIMELAPSE SEISMIC MEASUREMENTS
A method for aligning seismic events includes receiving a baseline image. The method also includes receiving a monitoring image. The method also includes an image processing operator to transform the signatures of the monitoring image to produce a signature-transformed monitoring image. The method also includes estimating one or more time-shift values based upon the baseline image and the signature-transformed monitoring image. The method also includes spatially transforming seismic events in the signature-transformed monitoring image to produce a repeatability-enforced image. The seismic events are spatially transformed by applying the one or more time-shift values to the signature-transformed monitoring image. The method also includes comparing the repeatability-enforced image with the baseline image to produce a loss function. The method also includes reducing the loss function to produce a final time-shift value and a final repeatability-enforced image. The method also includes displaying the final time-shift value and the final repeatability-enforced.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
A method for performing an asset analysis includes receiving first input data for a plurality of first assets. The method also includes building or training a large language model (LLM) based upon the first input data. The method also includes receiving second input data for a plurality of second assets. The method also includes receiving a request to screen one or more of the second assets. The request is to detect an anomaly and/or to improve a performance of one or more of the second assets. The method also includes selecting one or more screening tools using the LLM based upon the request. The method also includes determining an order to apply the one or more selected screening tools based upon the first input data, the second input data, and the request. The method also includes screening one or more of the second assets using the one or more selected screening tools in the order.
A wellbore fluid may include an oleaginous continuous phase; a non-oleaginous discontinuous phase; an emulsifier stabilizing the non-oleaginous phase within the oleaginous phase; a low density material selected and in an amount to result in a specific gravity of the wellbore fluid that is less than 0.83; and at least one rheology modifier selected to suspend the low density material within the wellbore fluid.
A technique facilitates control over a downhole well operation. The technique utilizes an electronic control system for controlling actuation of a valve downhole. The valve, in turn, is operated to enable selective control over fluid flows governing the actuation of a downhole tool and/or other downhole operations. In some embodiments, the electronic control system may work in cooperation with a downhole hydraulic system to provide a downhole electro-hydraulically actuated valve system. A monitoring system provides feedback regarding the valve position and/or status of the downhole operation.
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 23/04 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells operated by fluid means, e.g. actuated by explosion
F16K 37/00 - Special means in or on valves or other cut-off apparatus for indicating or recording operation thereof, or for enabling an alarm to be given
A fluid testing system includes a fluid container with an inner surface that defines a chamber. The fluid testing system also includes a spray bar that extends circumferentially about at least a portion of the chamber, wherein the spray bar includes multiple cleaning fluid outlets to spray a cleaning fluid onto the inner surface that defines the chamber.
B08B 9/093 - Cleaning of containers, e.g. tanks by the force of jets or sprays
B08B 5/02 - Cleaning by the force of jets, e.g. blowing-out cavities
B08B 7/02 - Cleaning by methods not provided for in a single other subclass or a single group in this subclass by distortion, beating, or vibration of the surface to be cleaned
B08B 9/087 - Cleaning of containers, e.g. tanks by methods involving the use of tools, e.g. brushes, scrapers
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
14.
SYSTEM AND METHOD FOR MULTIDIMENSIONAL DECONVOLUTION
Systems and methods are provided for performing multidimensional deconvolution. An exemplary method includes: receiving, using at least one processor, a first data associated with waves propagating in a seismic structure; selecting, using the at least one processor, a first transform to be applied to the first data; determining, using the least one processor, whether the first transform is a sparsity or rank revealing transform to optimize sparsity or rank minimization; if the first transform is the sparsity or rank transform, applying, using the at least one processor, the first transform to the first data to produce a second data; calculating, using the at least one processor and the second data, at least one Green's function associated with the first data; and predicting, using the at least one processor and the at least one Green's function, material properties throughout the seismic structure to facilitate exploratory and/or production operations.
An expandable tool includes a reamer block, a cutting element coupled to the reamer block, and a brake element embedded in the reamer block. The cutting element includes a cutting face extending to a gauge radius of the reamer block. The cutting element has a cutting rake angle formed on a radial plane between the cutting face and a normal line orthogonal to a borehole wall. The brake element includes an engagement face extending less than the cutting diameter. The brake element has a brake rake angle that is different than the cutting rake angle, such as by at least 45°. The brake rake angle is defined between the engagement face and the normal line.
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
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
A thermal system includes a first facility fluid circuit including a facility fluid for circulating through a facility, a first facility heat exchanger, and a first facility supply inlet for providing the facility fluid to the facility. A second facility fluid circuit includes the facility fluid, a second facility fluid heat exchanger, and a second facility supply inlet. A ground-source heat pump includes the first facility heat exchanger and is associated with the first facility fluid circuit. An air-source heat pump includes the second facility heat exchanger and is associated with the second facility heat exchanger. A mutual supply duct connects the first and second facility fluid circuits such that the first facility fluid circuit is fluidly connected to the second facility supply inlet and the second facility fluid circuit is connected to the first facility supply inlet.
A ringout detection system may receive a plurality of surface weight-on-bit (SWOB) measurements from a surface weight-on-bit (WOB) sensor and a plurality of downhole weight-on-bit (DWOB) measurements from a downhole WOB sensor. A ringout detection system may identify a decrease in a WOB ratio between the plurality of SWOB measurements and the plurality of DWOB measurements. A ringout detection system may determine that the decrease in the WOB ratio exceeds a WOB ratio threshold. A ringout detection system may identify that ringout has occurred at the reamer based at least in part on the decrease in the WOB ratio.
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 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 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
18.
TIME DOMAIN STACKING OF ACOUSTIC DIPOLE LWD MEASUREMENTS
A method for acoustic logging a wellbore includes making a plurality of directional sonic logging measurements while rotating an acoustic logging tool in a wellbore. A plurality of orthogonal pairs of measurements are identified among the measurements. Each of the orthogonal pairs includes a first measurement having a measured angle of a transmitter firing direction that is perpendicular with a measured angle of a transmitter firing direction of a second measurement within a predetermined tolerance. A set of 4C component waveforms is compiled for each of the identified orthogonal pairs and mathematically rotated to align with predefined axes. Selected ones of the rotated waveforms are then stacked in the time domain.
A method for acoustic logging a wellbore includes making a plurality of directional sonic logging measurements while rotating an acoustic logging tool in a wellbore. A noise component of each of the measurements is compared with a threshold. Measurements for which the noise component is greater than the threshold are discarded. Measurements for which the noise component is less than the threshold are retained.
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
A thermal system includes a first facility fluid circuit including a facility fluid for circulating through a facility, a first facility heat exchanger, and a first facility supply inlet for providing the facility fluid to the facility. A second facility fluid circuit includes the facility fluid, a second facility fluid heat exchanger, and a second facility supply inlet. A ground-source heat pump includes the first facility heat exchanger and is associated with the first facility fluid circuit. An air-source heat pump includes the second facility heat exchanger and is associated with the second facility heat exchanger. A mutual supply duct connects the first and second facility fluid circuits such that the first facility fluid circuit is fluidly connected to the second facility supply inlet and the second facility fluid circuit is connected to the first facility supply inlet.
F24F 11/81 - Control systems characterised by their outputsConstructional details thereof for controlling the temperature of the supplied air by controlling the air supply to heat-exchangers or bypass channels
F24F 5/00 - Air-conditioning systems or apparatus not covered by group or
F24F 11/65 - Electronic processing for selecting an operating mode
A needle for a choke valve assembly includes a base portion formed from a first non-superhard material and a tip portion formed from a superhard material. The needle also includes a brazed connection coupling the tip portion to the base portion. The brazed connection includes an insert formed from a second non-superhard material, in which the second non-superhard material is harder than the first non-superhard material and softer than the superhard material. In addition, the brazed connection includes a shim disposed between the insert and the base portion, a first layer of brazing material disposed between the base portion and the shim, and a second layer of brazing material disposed between the shim and the insert.
The disclosure focuses on a drilling system that uses a horizon mapping system to actively determine resistivity change interfaces that form a horizon in subsurface geological features. In various implementations, the horizon mapping system uses a resistivity image mapping neural network to efficiently and accurately generate horizon maps of subsurface geological features, such as reservoirs, from resistivity images. Additionally, the horizon mapping system may generate augmented resistivity images labeled with a horizon map in real time as data and measurements are received.
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
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
23.
GENERATING RISK ANALYSIS REPORTS FOR DRILLING A WELLBORE USING A RISK MODEL
A drilling risk analysis system may provide, on a graphical user interface (GUI) of a computing device, a selectable work icon associated with a modular work item of a wellbore plan. Based on receiving a work icon selection of the selectable work icon, the drilling risk analysis system may provide, on the GUI, a selectable event icon associated with historical events related to the modular work item associated with the selectable work icon. The drilling risk analysis system may, based on receiving an event icon selection of the selectable event icon, apply a risk model to the modular work item. The risk model performs a risk analysis of an event likelihood and event severity of an event related to the historical events and generates a risk analysis report of the event. The drilling risk analysis system may present the risk analysis report of the event on the GUI.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A method for producing a high-fidelity, high-resolution seismic image of a subsurface of a wellsite. The method includes receiving seismic data from wellsite equipment that is disposed at a wellsite. An initial estimation of an earth model is recovered from the received data and a depth migration workflow is performed that is based on the initial estimation of the earth model. The depth migration workflow may be a least-squares FWI-derived reflectively (LS-FDR) workflow. The method also includes revising the initial estimation of the earth model based on the results of the depth migration workflow in order to produce an optimal estimation of the earth model. A seismic image may then be generated from the optimal estimation of the earth model and displayed on a screen for a user. The user may then perform a wellsite action that is based on the generated seismic image.
A method for enhancing a resolution of a seismic image with reference well log measurements includes receiving a first low-resolution seismic image. The method also includes generating one or more pseudo well logs based upon the first low-resolution seismic image. The method also includes generating synthetic seismic traces. The synthetic seismic traces include (1) synthetic low-resolution seismic traces that are based upon the first low-resolution seismic image and the one or more pseudo well logs and (2) synthetic high-resolution seismic traces that are based upon a targeted high-resolution seismic image and the one or more pseudo well logs. The method also includes training a convolutional neural network to map the synthetic low-resolution seismic traces to the synthetic high-resolution seismic traces. The method also includes generating the targeted high-resolution seismic image using the trained convolutional neural network.
A method for acoustic logging a wellbore includes making a plurality of directional sonic logging measurements while rotating an acoustic logging tool in a wellbore. A plurality of orthogonal pairs of measurements are identified among the measurements. Each of the orthogonal pairs includes a first measurement having a measured angle of a transmitter firing direction that is perpendicular with a measured angle of a transmitter firing direction of a second measurement within a predetermined tolerance. A set of 4C component waveforms is compiled for each of the identified orthogonal pairs and mathematically rotated to align with predefined axes. Selected ones of the rotated waveforms are transformed to a frequency domain and stacked in the frequency domain to compute a median or average slowness at each of a plurality of frequencies.
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
An expandable tool includes a reamer block, a cutting element coupled to the reamer block, and a brake element embedded in the reamer block. The cutting element includes a cutting face extending to a gauge radius of the reamer block. The cutting element has a cutting rake angle formed on a radial plane between the cutting face and a normal line orthogonal to a borehole wall. The brake element includes an engagement face extending less than the cutting diameter. The brake element has a brake rake angle that is different than the cutting rake angle, such as by at least 45°. The brake rake angle is defined between the engagement face and the normal line.
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
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 45/00 - Measuring the drilling time or rate of penetration
A ringout detection system may receive a plurality of surface weight-on-bit (SWOB) measurements from a surface weight-on-bit (WOB) sensor and a plurality of downhole weight-on-bit (DWOB) measurements from a downhole WOB sensor. A ringout detection system may identify a decrease in a WOB ratio between the plurality of SWOB measurements and the plurality of DWOB measurements. A ringout detection system may determine that the decrease in the WOB ratio exceeds a WOB ratio threshold. A ringout detection system may identify that ringout has occurred at the reamer based at least in part on the decrease in the WOB ratio.
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 7/28 - Enlarging drilled holes, e.g. by counterboring
A method can include using a digital camera of a digital microscopy system, acquiring a digital image of an engineered three-dimensional object positioned on a base and illuminated by a light source; using the digital camera, acquiring a digital image of a color checker card positioned on the base and illuminated by the light source; determining a light source criterion by assessing position of the light source based at least in part on a shadow in the digital image of the engineered three-dimensional object as castby the engineered three-dimensional object and based at least in part on saturation of color in the digital image of the color checker card; and calibrating the digital microscopy system using the light source criterion to generate a calibrated digital microscopy system.
A method for determining locations for wind turbine installations at a site. The method includes receiving data from a site, wherein the data includes geotechnical data such as borehole measurements and geophysical data such as high resolution shallow seismic data, magnetometer data, and sonar images. The method includes conditioning the received data by interpreting the received data for key soil boundaries and mechanical properties that are related to a shallow subsurface of the site. The method also includes generating a ground model of the site. The ground model may be continuously updated with newly received data or interpretation updates. The ground model may also be displayed on a screen. The method also includes performing a site action based on the ground model including selecting where to install one or more heavy wind turbine structures within the site.
G06F 30/13 - Architectural design, e.g. computer-aided architectural design [CAAD] related to design of buildings, bridges, landscapes, production plants or roads
A method includes receiving seismic data of a subsurface. The method also includes color processing the seismic data to produce color-processed seismic data. The method also includes performing a seismic interpretation on the color-processed seismic data to identify regional geologic features. The method also includes performing first mapping along the regional geologic features to identify local geologic features. The method also includes extracting reservoir bodies from the local geologic features based upon the first mapping. The method also includes performing second mapping along the local geologic features to embed the local geological features into the regional geologic features. The method also includes delineating boundaries of reservoirs or seals in the subsurface based upon the local geologic features that are embedded into the regional geologic features. The method also includes de-risking a fluid prospect in a fluid reservoir based upon the boundaries of the reservoirs or the seals.
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
A method for performing an asset analysis includes receiving first input data for a plurality of first assets. The method also includes building or training a large language model (LLM) based upon the first input data. The method also includes receiving second input data for a plurality of second assets. The method also includes receiving a request to screen one or more of the second assets. The request is to detect an anomaly and/or to improve a performance of one or more of the second assets. The method also includes selecting one or more screening tools using the LLM based upon the request. The method also includes determining an order to apply the one or more selected screening tools based upon the first input data, the second input data, and the request. The method also includes screening one or more of the second assets using the one or more selected screening tools in the order.
An energy efficient and environmentally benign lithium recovery process is described. The process comprises extracting lithium from the brine source using a ion withdrawal process to form a lithium extract; providing electricity for the extracting using an energy source; and recovering thermal energy from the energy source for use in the extracting.
A downhole tool includes a body having a longitudinal axis and a fluid passage extending through the body. The downhole tool includes at least one blade having one or more engagement faces thereon. At least one junk slot extends adjacent to the at least one blade. The downhole tool includes a cleaning element at the longitudinal axis of the body. The cleaning element has a substrate bore in fluid communication with the fluid passage. The cleaning element includes at least one opening or passing a fluid from the substrate bore and out of the downhole tool through the at least one junk slot. A flow direction of the at least one opening is offset from the longitudinal axis.
A downhole tool includes a body having a longitudinal axis and a fluid passage extending through the body. The downhole tool includes at least one blade having one or more engagement faces thereon. At least one junk slot extends adjacent to the at least one blade. The downhole tool includes a cleaning element at the longitudinal axis of the body. The cleaning element has a substrate bore in fluid communication with the fluid passage. The cleaning element includes at least one opening or passing a fluid from the substrate bore and out of the downhole tool through the at least one junk slot. A flow direction of the at least one opening is offset from the longitudinal axis.
A method for determining locations for wind turbine installations at a site. The method includes receiving data from a site, wherein the data includes geotechnical data such as borehole measurements and geophysical data such as high resolution shallow seismic data, magnetometer data, and sonar images. The method includes conditioning the received data by interpreting the received data for key soil boundaries and mechanical properties that are related to a shallow subsurface of the site. The method also includes generating a ground model of the site. The ground model may be continuously updated with newly received data or interpretation updates. The ground model may also be displayed on a screen. The method also includes performing a site action based on the ground model including selecting where to install one or more heavy wind turbine structures within the site.
A method for contextualizing a 3D reservoir includes receiving input data corresponding to the 3D reservoir. The method also includes processing and interpreting the input data to produce stratigraphic and/or structural insights. The method also includes processing and interpreting the input data to produce petrophysical insights. The method also includes determining a structure of the 3D reservoir based upon the input data, the stratigraphic and/or structural insights, and the petrophysical insights. The method also includes determining depositional facies of the 3D reservoir based upon the structure. The method also includes determining petrophysical property distributions of the 3D reservoir based upon the structure only and/or based upon the structure and the depositional facies.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
Techniques and systems for motion detection of a logging tool. A system includes a nuclear magnetic resonance (NMR) logging tool configured to perform at least one Carr-Purcell-Meiboom-Gill (CPMG) scan utilizing a plurality of distinct echo times (tE) in conjunction with a single excitation pulse and a single wait time as a multiple echo spacing sequence to acquire NMR logging measurements and a processing system coupled to the NMR logging tool, wherein the processing system is configured to process the NMR logging measurements acquired by the NMR logging tool to determine whether the NMR logging measurements were affected by lateral motion of the NMR logging tool.
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 47/13 - 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
39.
METHODS OF FORMING ORGANOPHILIC FLUID LOSS MATERIALS, AND RELATED ORGANOPHILIC FLUID LOSS MATERIALS AND METHODS
A method of forming a fluid loss material for a wellbore fluid includes mixing tannin at least one modifier to form a mixture, heating the mixture to a temperature greater than about 100° C. to react the tannin with the at least one modifier to form a modified tannin, and reacting the modified tannin with an amine to form an organophilic fluid loss material comprising the amine bonded to the modified tannin. Related organophilic fluid loss materials and methods of operating a wellbore are also disclosed.
C09K 8/44 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing organic binders only
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
40.
WELLBORE FLUIDS INCLUDING SHALE INHIBITORS, AND RELATED METHODS
A method of operating a wellbore comprises mixing a dry shale inhibitor comprising a solid amine salt with a fluid to form a drilling fluid. The drilling fluid comprises an aqueous base fluid and a shale inhibitor formed from the dry shale inhibitor, the shale inhibitor comprising the dissolved amine salt, the amine salt comprising a reaction product of at least one amine selected from the group consisting of selected from the group consisting of hexamethylenediamine, 1,8-diaminooctane, 1,10-diaminodecane, bis(para-aminocyclohexyl) methane, and tetramethyl hexamethylenediamine and at least one acid selected from the group consisting of hydrochloric acid, hydrobromic acid, hydroiodic acid, sulfuric acid, phosphoric acid, methanesulfonic acid, toluene sulfonic acid, trifluoromethanesulfonic acid, and trifluoracetic acid. The method further comprises pumping the wellbore fluid into a wellbore extending through an earth formation. Related wellbore fluids, methods of forming the dry shale inhibitor, and packages including the dry shale inhibitor are also disclosed.
The disclosure focuses on a drilling system that uses a horizon mapping system to actively determine resistivity change interfaces that form a horizon in subsurface geological features. In various implementations, the horizon mapping system uses a resistivity image mapping neural network to efficiently and accurately generate horizon maps of subsurface geological features, such as reservoirs, from resistivity images. Additionally, the horizon mapping system may generate augmented resistivity images labeled with a horizon map in real time as data and measurements are received.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
A downhole tool includes a body having a longitudinal axis and a fluid passage extending through the body. The downhole tool includes at least one blade having one or more engagement faces thereon. At least one junk slot extends adjacent to the at least one blade. The downhole tool includes a cleaning element at the longitudinal axis of the body. The cleaning element has a substrate bore in fluid communication with the fluid passage. The cleaning element includes at least one opening or passing a fluid from the substrate bore and out of the downhole tool through the at least one junk slot. A flow direction of the at least one opening is offset from the longitudinal axis.
A downhole tool includes a body having a longitudinal axis and a fluid passage extending through the body. The downhole tool includes at least one blade having one or more engagement faces thereon. At least one junk slot extends adjacent to the at least one blade. The downhole tool includes a cleaning element at the longitudinal axis of the body. The cleaning element has a substrate bore in fluid communication with the fluid passage. The cleaning element includes at least one opening or passing a fluid from the substrate bore and out of the downhole tool through the at least one junk slot. A flow direction of the at least one opening is offset from the longitudinal axis.
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
44.
GENERATING RISK ANALYSIS REPORTS USING A RISK MODEL
A drilling risk analysis system may provide, on a graphical user interface (GUI) of a computing device, a selectable work icon associated with a modular work item of a wellbore plan. Based on receiving a work icon selection of the selectable work icon, the drilling risk analysis system may provide, on the GUI, a selectable event icon associated with historical events related to the modular work item associated with the selectable work icon. The drilling risk analysis system may, based on receiving an event icon selection of the selectable event icon, apply a risk model to the modular work item. The risk model performs a risk analysis of an event likelihood and event severity of an event related to the historical events and generates a risk analysis report of the event. The drilling risk analysis system may present the risk analysis report of the event on the GUI.
G06F 3/04817 - Interaction techniques based on graphical user interfaces [GUI] based on specific properties of the displayed interaction object or a metaphor-based environment, e.g. interaction with desktop elements like windows or icons, or assisted by a cursor's changing behaviour or appearance using icons
G06F 3/0484 - Interaction techniques based on graphical user interfaces [GUI] for the control of specific functions or operations, e.g. selecting or manipulating an object, an image or a displayed text element, setting a parameter value or selecting a range
G06Q 10/0635 - Risk analysis of enterprise or organisation activities
A method can include receiving a target density value for a drilling fluid exiting a sedimentation device; receiving a measured density value for the drilling fluid directed to the sedimentation device, a measured density value for the drilling fluid exiting the sedimentation device, and an incoming flow rate value for the drilling fluid directed to the sedimentation device; and generating control instructions for control of an injection pump to regulate a diluent injection pump rate to dilute the drilling fluid entering the sedimentation device to achieve the target density value.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
E21B 7/18 - Drilling by liquid or gas jets, with or without entrained pellets
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
46.
DEVICES AND SYSTEMS FOR CUTTING ELEMENT ASSEMBLIES
A cutting element assembly includes a cutter support including a cutter bore. A cutting element is in the cutter bore and a resilient element is integral with the cutter support. The resilient element is longitudinally compressible and has a displacement of greater than 0.1 mm and optionally less than 2 mm. Another cutting assembly includes a cutter support coupled to multiple cutting elements. A resilient element of the cutter support is compressible based on a force applied to the cutter support through one or more of the cutting elements. The resilient element can include a slit in the cutter support. A slit may, for instance, extend perpendicular or transverse to an axis of the cutting elements and allow the cutter support to flex and close off or reduce a size of the slit when forces act on one or more of the cutting elements.
Devices, systems, and methods for drying wet cuttings for imaging are described herein. In some examples, one or more embodiments include a device comprising a frame, a perforated liner connected to the frame, where the perforated liner is to receive cuttings generated from a downhole tool during a drilling operation, and a cap connected to a top portion of the frame to prevent the cuttings from exiting the perforated liner.
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 21/06 - Arrangements for treating drilling fluids outside the borehole
G01N 15/0227 - Investigating particle size or size distribution by optical means using imagingInvestigating particle size or size distribution by optical means using holography
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
37 - Construction and mining; installation and repair services
Goods & Services
Subsurface drill bit with sensors that convert measurements at the drill bit to bore hole images of the geological formation. Services in the field of providing borehole images while drilling a subsurface well
49.
WELLBORE FLUIDS INCLUDING EMULSIFIER COMPOSITIONS, AND RELATED METHODS OF OPERATING A WELLBORE AND FORMING THE EMULSIFIER COMPOSITIONS
A wellbore fluid includes a base fluid and an emulsifier composition comprising an emulsifier and glycerol. The emulsifier comprises a reaction product of a bis-amide and at least one of maleic acid, maleic anhydride, fumaric acid, succinic acid, or succinic anhydride. The bis-amide includes a reaction product of one or more fatty acid esters and a polyalkylamine. Related methods of operating a wellbore and forming the emulsifier composition are also disclosed.
A system and method for determining a subsurface horizon in a drilling system that include generating a resistivity change interface using a resistivity image mapping neural network that determines horizon boundaries of geological features by encoding resistivity images of subsurface feature sections into feature vectors and decoding the feature vectors into the horizon boundaries. The system and method also include generating an augmented resistivity image based on the resistivity change interface and a resistivity image. The system and method further include providing the augmented resistivity image for display on a computing device to indicate a horizon boundary.
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
Devices, systems, and methods for downhole monitoring are described herein. In some examples, one or more embodiments include a memory and a processor to execute instructions stored in the memory to capture drilling data from a sensor associated with a bottom hole assembly, store the drilling data in a buffer, in response to the buffer exceeding a threshold capacity, classify the drilling data into a plurality of categories, and transmit the classified drilling data uphole to a computing device.
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 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 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
Devices, systems, and methods for a pump rubber of a degasser pump are described herein. In some examples, one or more embodiments include a first number of materials forming an inner surface of the pump rubber and a second number of materials forming an outer surface of the pump rubber. The pump rubber can be configured as a hollowed elongated cylinder. The first number of materials can be configured to provide abrasion resistance to wear from a drilling fluid that is passed through the pump rubber and resistance to thermal and chemical stress from a drilling fluid that is passed through the pump rubber. The second number of materials can be configured to provide fatigue resistance when compressing and decompressing the pump rubber.
A wellbore fluid includes a base fluid and an emulsifier composition comprising an emulsifier and glycerol. The emulsifier comprises a reaction product of a bis-amide and at least one of maleic acid, maleic anhydride, fumaric acid, succinic acid, or succinic anhydride. The bis-amide includes a reaction product of one or more fatty acid esters and a polyalkylamine. Related methods of operating a wellbore and forming the emulsifier composition are also disclosed.
Luminescent diamond is made by creating vacancies in diamond grains and heat treating the diamond grains by controlling a thickness of the diamond grains on a substrate. The heat treatment may occur in a temperature range that does not burn the diamond grains, and the controlled thickness produces an even color change and/or promotes oxygen terminations on the diamond particle surfaces.
Devices, systems, and methods for downhole monitoring are described herein. In some examples, one or more embodiments include a memory and a processor to execute instructions stored in the memory to capture drilling data from a sensor associated with a bottom hole assembly, store the drilling data in a buffer, in response to the buffer exceeding a threshold capacity, classify the drilling data into a plurality of categories, and transmit the classified drilling data uphole to a computing device.
E21B 44/04 - Automatic control of the tool feed in response to the torque of the drive
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
A perforation tool features a container with a longitudinal axis; an initiator module in the container, the initiator module having a firing circuit, an electrical contact at the longitudinal axis, and a detonator housing; and a shaped charge frame in the container, the shaped charge frame having a first end; a second end opposite the first end; a recess for accepting a shaped charge between the first end and the second end, the recess having a wide end and a narrow end, wherein the longitudinal axis is between the wide end and the narrow end; a first electrical contact at the first end, the first electrical contact located at the longitudinal axis; a second electrical contact at the second end, the second electrical contact located at the longitudinal axis; an electrical conductor connecting the first and second contacts; and a ballistic pathway coupling the detonator housing to the narrow end of the recess.
Methods, systems, and computer readable storage mediums for managing testing of a well to facilitate completion of the well is disclosed. The system may include a tool usable to perform testing on the well. The tool may include a circulation assembly and a hydraulic assembly. The circulation assembly may be reconfigurable by selectively isolating an annulus of the well from a fluid chamber of the circulation assembly. The hydraulic assembly may facilitate reconfiguration of the circulation assembly to selectively isolate the annulus, and facilitate flowing of various fluids and gasses to perform the testing.
The invention relates to a plant (1) for producing dihydrogen, comprising an electrochemical device (2) and a fluidic network which comprises at least one inlet duct (11, 16, 61-64) configured to convey an inlet stream comprising a fluid, such as water in the gaseous state, to the electrochemical device (2), the fluidic network comprising at least one recirculation branch (RC1) configured to inject a portion of an outlet stream that comprises dihydrogen into the at least one inlet duct (11), the electrochemical device (2) being configured to form the dihydrogen of the outlet stream from the inlet stream. The invention also relates to a corresponding method for producing dihydrogen.
C25B 15/08 - Supplying or removing reactants or electrolytesRegeneration of electrolytes
F04F 5/00 - Jet pumps, i.e. devices in which fluid flow is induced by pressure drop caused by velocity of another fluid flow
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
59.
Deep Learning System for Casing Centralization Estimation Through Pulse-Echo TIE Interference
Methods and apparatus to analyze data related to ultrasonic images. The method can include selecting a training dataset and generating labels and classes from the selected training dataset. The method can also include obtaining a model through artificial intelligence from a pretrained computer model, the selected training dataset and the generated labels and classes. The method can further include using the obtained model to evaluate eccentering from the ultrasonic images and obtaining ultrasonic images related to a downhole environment The method also includes determining a recipe to score a set of the ultrasonic images of the downhole environment and using the recipe to score and select a resulting dataset of ultrasonic images and updating the training dataset with the resulting dataset of ultrasonic images.
A method can include receiving seismic data from a three-dimensional seismic survey of a subsurface region that includes multiple horizons; determining an order of a set of points according to data quality metric values of the seismic data, where each point in the set of points is associated with one of the multiple horizons; tracking the multiple horizons serially, where one or more switching criteria cause the tracking to switch from one of the multiple horizons to another one of the multiple horizons according to the order of the set of points; and, based on the tracking, outputting a three-dimensional model of the multiple horizons in the subsurface region.
The invention relates to a plant for treating gases containing hydrogen sulphide (H2S), the plant comprising: - a Claus-type sulphur recovery unit (1), the sulphur recovery unit (1) receiving, as input: a first stream comprising a gas containing H2S and a second stream comprising a gas that comprises O2; - a high-temperature steam electrolysis unit receiving, as input, a first stream comprising water vapour and supplying, as output, a second stream comprising O2 gas and a third stream comprising H2 gas. The invention is characterised in that the plant further comprises a water vapour forming unit (3) comprising means for recovering the heat from the sulphur recovery unit (1), this heat being used to produce at least some of the water vapour of the first stream received by the electrolysis unit.
C02F 3/26 - Activated sludge processes using pure oxygen or oxygen-rich gas
C25B 1/042 - Hydrogen or oxygen by electrolysis of water by electrolysis of steam
C10G 45/02 - Refining of hydrocarbon oils using hydrogen or hydrogen-generating compounds to eliminate hetero atoms without changing the skeleton of the hydrocarbon involved and without cracking into lower boiling hydrocarbonsHydrofinishing
62.
FLUIDISED CATALYTIC CRACKING UNIT COMPRISING AN ELECTROLYSER
The invention relates to a fluidised catalytic cracking unit comprising: - a reactor (1); - at least one catalyst regenerator (4) designed to feed the reactor with catalyst (3) and to be fed with spent catalyst (7) by the reactor; and - a solid oxide electrolyser (100) capable of producing dioxygen (11) and dihydrogen (12) from a stream comprising in particular water vapour (V1), the solid oxide electrolyser comprising a first outlet for discharging dioxygen and a second outlet for discharging dihydrogen, the first outlet being connected to the catalyst regenerator by means of a feed line for feeding the regenerator, to feed an inlet (41) of the regenerator with dioxygen. The unit comprises a facility (110) for treating a gas stream (9) discharged at the outlet of the regenerator, the facility comprising a facility outlet for discharging a treated gas stream (90), the facility outlet being connected to the feed line for feeding the regenerator.
C10G 11/18 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils with preheated moving solid catalysts according to the "fluidised bed" technique
C10G 11/20 - Catalytic cracking, in the absence of hydrogen, of hydrocarbon oils by direct contact with inert heated gases or vapours
C25B 1/042 - Hydrogen or oxygen by electrolysis of water by electrolysis of steam
63.
DEEP LEARNING SYSTEM FOR CASING CENTRALIZATION ESTIMATION THROUGH PULSE-ECHO TIE INTERFERENCE
Methods and apparatus to analyze data related to ultrasonic images. The method can include selecting a training dataset and generating labels and classes from the selected training dataset. The method can also include obtaining a model through artificial intelligence from a pretrained computer model, the selected training dataset and the generated labels and classes. The method can further include using the obtained model to evaluate eccentering from the ultrasonic images and obtaining ultrasonic images related to a downhole environment The method also includes determining a recipe to score a set of the ultrasonic images of the downhole environment and using the recipe to score and select a resulting dataset of ultrasonic images and updating the training dataset with the resulting dataset of ultrasonic images.
A rotating check valve is disclosed for improved debris collection within a wellbore. The check valve can be part of a debris removal tool that includes a motor, pump, gearbox, bailer, milling bit, the check valve, rotational shafts. On its uphole end, the check valve can be coupled with the bailer such that the check valve can rotate relative to the bailer. Also on the uphole end, the check valve can be rotationally coupled to a shaft that passes through the bailer and couples with the gearbox. On the downhole end, the check valve can be rotationally coupled to the milling bit. The check valve can include a torque transfer mechanism that transfers torque generated by the motor and gearbox to the milling bit. The check valve can include a unidirectional flow control mechanism that restricts the flow of fluid and debris to the uphole direction.
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 34/06 - Valve arrangements for boreholes or wells in wells
Systems and methods are provided that store and release compressed gas, which include an accumulator for storing compressed gas, a gas compressor, a thermal storage subsystem, a plurality of secondary heater stages and a corresponding plurality of gas expander stages, and a secondary heat source. During accumulation operations, the thermal storage subsystem is configured to extract heat from the compressed gas produced by the gas compressor and supplied to the accumulator and store the extracted heat. During the expansion operations, the secondary heater stages and gas expander stages are configured to heat and expand compressed gas supplied from the accumulator and heated by the thermal storage subsystem. The secondary heater stages use heat supplied by the secondary heat source. The secondary heat source can extract heat from a green or renewable system or an industrial process located at or near the system that stores and releases compressed gas.
F02C 6/16 - Gas-turbine plants having means for storing energy, e.g. for meeting peak loads for storing compressed air
F02C 6/18 - Plural gas-turbine plantsCombinations of gas-turbine plants with other apparatusAdaptations of gas-turbine plants for special use using the waste heat of gas-turbine plants outside the plants themselves, e.g. gas-turbine power heat plants
66.
Integrated hybrid solar energy plant and district heating and cooling network
A system may include a solar thermal collector including a photovoltaic (PV) module, wherein the solar thermal collector is configured to convert a first portion of sunlight to thermal energy and a second portion of the sunlight to electrical energy. A system may include a thermal cycle generator configured to generate electricity including a generator working fluid, wherein the generator working fluid receives heat from the solar thermal collector and exhausts heat to a district working fluid. A system may include a district working fluid ring of a district heating and cooling network (DHCN) configured to receive heat from the thermal cycle generator with the district working fluid therein.
H02S 40/44 - Means to utilise heat energy, e.g. hybrid systems producing warm water and electricity at the same time
F24S 10/95 - Solar heat collectors using working fluids using internal thermosiphonic circulation having evaporator sections and condenser sections, e.g. heat pipes
F24S 40/55 - Arrangements for cooling, e.g. by using external heat dissipating means or internal cooling circuits
A system may include a solar collector configured to receive sunlight, wherein the solar collector includes a solar thermal collector and a photovoltaic (PV) module. A system may include a hot energy storage (HES) configured to receive solar heat from the solar thermal collector and heat the HES to a first temperature range. A system may include a cold energy storage (CES). A system may include a refrigeration unit for cooling the CES to a second temperature range less than the first temperature range. A system may include a thermodynamic generator configured to provide electricity to the refrigeration unit based on a temperature difference between the HES and a heat sink. A system may include a load including one or more electrical devices and a load fluid circuit for cooling the load, wherein the load fluid circuit is in thermal communication with the CES.
A method can include performing optical character recognition on a document to define spatial locations of bounding boxes for characters, where each bounding box includes at least one character; identifying a spatial location of keyword characters via a corresponding one of the bounding boxes; applying an edge detection technique to generate a skeletonized version of the document; determining borders within the skeletonized version of the document to define regions; and extracting the characters within one of the regions that includes the keyword characters.
Certain aspects of the present disclosure relate to a battery. The battery includes at least one couple of current collectors. The battery includes an organic fluid flow space and an oxygen-containing fluid flow space. The battery includes one or more membrane electrode assemblies (MEAs). Each MEA includes an oxygen electrode, where the oxygen electrode is configured to catalyze a redox reaction of the oxygen-containing fluid and an oxygen evolution reaction. Each MEA also includes an ion conducting membrane and/or a porous separator paper, where the membrane or separator separates the oxygen electrode from the organic fluid flow space. The battery includes positive electrode terminals electrically connected to at least one MEA and at least one or more negative electrode terminals, where the positive electrode terminal and the negative electrode terminal are configured to generate an electrical current in response to external electrical loads or to a voltage applied to across positive and negative electrode terminals in response to a charge step associated redox reaction.
Continuous monitoring of density in extraction and recovery using pressure density sensors is described herein. Metal recovery methods and processes using pressure density sensors are also described herein. A method comprises providing an aqueous material containing target ions to a direct extraction unit; extracting target ions from the aqueous material containing target ions using a selective withdrawal medium to yield an extract and a depleted material; using a pressure density sensor to determine a first density of the aqueous material containing target ions; using a pressure density sensor to determine a second density of the depleted material; comparing the first density with the second density; and operating the direct extraction unit based on the comparison.
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
Methods, systems, and computer readable storage mediums for managing completion of a well for geothermal energy extraction is disclosed. The method may include obtaining a plurality of measurements of a geological formation in which a wellbore of the well is positioned. The method may also include, for each measurement of the plurality of measurements, obtaining a fluid flow analysis result for the geological formation to obtain fluid flow analysis results for the geological formation. The method may further include defining at least one zone along the wellbore based on the fluid flow analysis results. The method may also include ranking the at least one zone based on the fluid flow analysis results and a ranking system to obtain at least one ranked zone. The method may additionally include obtaining a formation model for the geological formation using the at least one ranked zone a thermal properties of the geological formation.
A method can include receiving seismic data from a three-dimensional seismic survey of a subsurface region that includes multiple horizons; determining an order of a set of points according to data quality metric values of the seismic data, where each point in the set of points is associated with one of the multiple horizons; tracking the multiple horizons serially, where one or more switching criteria cause the tracking to switch from one of the multiple horizons to another one of the multiple horizons according to the order of the set of points; and, based on the tracking, outputting a three-dimensional model of the multiple horizons in the subsurface region.
A system for capturing CO2 from a feed gas, including a CO2 absorption unit, a washing unit, and an adsorption unit. The CO2 absorption unit has an absorption section and a first inlet to receive the feed gas and a second inlet to receive an amine-containing solvent having properties for loading CO2. A first outlet drains a CO2-rich solvent, a second outlet drains a CO2-lean gas stream with less CO2 than the feed gas. The wash unit includes a washing section with an inlet to receive the CO2-lean gas stream and a second inlet for a washing liquid. A first outlet drains a loaded washing liquid with amines from the CO2-lean stream, and a second outlet for cleaned gas with reduced amine concentration. The adsorption unit has a vessel containing MOF bodies to extract amine from the loaded washing liquid.
B01J 20/22 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising organic material
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 53/02 - 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
74.
MONITORING AND MANAGING A GEOTHERMAL ENERGY SYSTEM
A geothermal management system may receive time-series data for operation of the geothermal energy system. A geothermal management system may calibrate a physical model using the time-series data. A geothermal management system may apply the physical model to a pre-determined comparison parameter to generate a performance indicator. A geothermal management system may identify an operating status of the geothermal energy system based on the performance indicator.
Embodiments presented provide for a workflow to identify a proposed metal-organic framework (MOF) to directly replace a sorbent material within a carbon dioxide capture system. The workflow disclosed and described below identifies target sorbent features associated with a sorbent material based on target sorbent properties. A subset of MOFs is selected from a MOF library based on reaction parameters of the target sorbent, and a machine learning algorithm is used to correlate MOF structures of the MOF training subset with the identified target sorbent features. A proposed MOF structure is identified as the most similar to the target sorbent.
B01D 53/02 - 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
B01D 53/30 - Controlling by gas-analysis apparatus
B01D 53/34 - Chemical or biological purification of waste gases
A method can include receiving data for a well in a field and parameter values for hydraulic fracturing of the well in the field; predicting production data responsive to the hydraulic fracturing of the well using at least a portion of the data and at least a portion of the parameter values as input to a machine learning model, where the machine learning model is trained using historical data for the field; and outputting the predicted production data.
Detection and quantification of elements of interest, such as lithium and manganese, in a subterranean aqueous material is described herein. A selective sorbent material is introduced to a subterranean location having an aqueous material to contact the aqueous material. The selective sorbent material is recovered from the subterranean location and an amount of an element of interest in the recovered selective sorbent material is determined.
The present disclosure provides techniques for obtaining a domain-specific model targeted for a downstream task. A method may include obtaining a plurality of unlabeled geospatially-indexed datasets from different geographic locations representing different subsurface geologic conditions; training a neural network model on the plurality of unlabeled geospatially-indexed datasets in a self-supervised manner to obtain a foundation model that develops generalizable representations capturing shared interrelationships across the different subsurface geologic conditions; obtaining a labeled geospatially-indexed training dataset specific to a designated survey area; adapting parameters of the foundation model through retraining using the labeled geospatially-indexed training dataset to develop a domain-specific model targeted for a prediction task in the designated survey area; and implementing the domain-specific model on new geospatially-indexed input data from the designated survey area to generate predictions tied to locations for the targeted prediction task.
Embodiments presented provide for an arrangement for sampling fluids from a downhole environment. In specific embodiments, the arrangements provided prevent mixing of hydrocarbon fluids with mud filtrates that may be present in the geological stratum. In one embodiment an arrangement for sampling downhole fluid includes a body having at least one sample inlet and at least one guard inlet, a first line connected to the at least one sample inlet, a second line connected to the at least one guard inlet, and a segregation chamber connected to the first line and the second line, where the segregation chamber is configured to separate hydrocarbon fluids from other downhole fluids.
Use of a drilling fluid during wellbore drilling operations may result in a layer of drilling fluid particles and other solids, that build up on a sidewall of a wellbore and penetrate radially into a near wellbore zone of the sidewall. Disclosed is an apparatus which includes a downhole tool operable to be conveyed within a wellbore and remove mudcake from a sandface of the wellbore when the downhole tool is being conveyed within the wellbore, where the downhole tool includes a body, a plurality of scrapers that contact the sandface and remove the mudcake from the sandface when the downhole tool is being conveyed within the wellbore, and a plurality of arms each carrying a corresponding one of the scrapers, wherein each arm is operable to extend away from the body such that the scraper contacts the sandface when the downhole tool is being conveyed within the wellbore.
E21B 49/06 - 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 using side-wall drilling tools or scrapers
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
A system may include a solar collector configured to receive sunlight, wherein the solar collector includes a solar thermal collector and a photovoltaic (PV) module. A system may include a hot energy storage (HES) configured to receive solar heat from the solar thermal collector and heat the HES to a first temperature range. A system may include a cold energy storage (CES). A system may include a refrigeration unit for cooling the CES to a second temperature range less than the first temperature range. A system may include a thermodynamic generator configured to provide electricity to the refrigeration unit based on a temperature difference between the HES and a heat sink. A system may include a load including one or more electrical devices and a load fluid circuit for cooling the load, wherein the load fluid circuit is in thermal communication with the CES.
Systems and methods presented facilitate determination of contact forces between intervention strings and casings. In embodiments, a method includes detecting, via one or more sensors, data relating to a plurality of downhole operating parameters within a wellbore at least partially cased by a casing. The method also includes receiving, via a processing system, the data relating to the plurality of downhole operating parameters from the one or more sensors. The method further includes calculating, via the processing system, contact forces between an intervention string deployed within the wellbore and an inner wall of the casing at a plurality of depths along the wellbore utilizing a theoretical model that uses the data relating to the plurality of downhole operating parameters as inputs, calculating an accumulative contact force between the intervention string and the inner wall of the casing, and tracking a resultant wear of the casing from job to job.
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
83.
METHOD FOR PERFORMING KICKSTART, LIFT AND WELL LOGGING OPERATIONS USING A CABLE DEPLOYED ELECTRICAL SUBMERSIBLE PUMP
A method for pumping fluid from a well includes moving the pump to a selected depth in a conduit within the well. The moving is performed by spooling an electrical cable. The pump is connected to the electrical cable. The pump has a resettable annular seal disposed between a pump intake and a pump discharge. The annular seal is set in the conduit. The pump is operated. The resettable annular seal is released and the pump is moved within the conduit.
A method for milling and removing debris in a wellbore, comprising: moving a collecting while milling (CWM) tool downhole into the wellbore; and conducting a first operation with the CWM tool, wherein the first operation comprises: a first cycle including operating a motor of the CWM tool at a first torque and a first speed, wherein the first operation includes milling an obstruction in a wellbore; and a second cycle including operating the motor of the CWM tool at a second torque and second speed to power a centrifugal pump to circulate wellbore fluid through a bailer of the CWM tool to collect debris, wherein the first torque is greater than the second torque and the second speed is greater than the first speed.
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 37/00 - Methods or apparatus for cleaning boreholes or wells
A method for evaluating a formation fluid includes flowing formation fluid through a flowline in a downhole fluid sampling and evaluation measurement tool deployed in a wellbore and making optical absorption measurements on the flowing formation fluid to generate a plurality of optical density spectra. A spectrum from the plurality of generated spectra is selected using predetermined selection criteria that are based on optical density values at one or more selected wavelengths in the generated spectra. At least one fluid property is estimated from the selected spectrum.
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
G01N 21/3577 - Investigating relative effect of material at wavelengths characteristic of specific elements or molecules, e.g. atomic absorption spectrometry using infrared light for analysing liquids, e.g. polluted water
G01N 21/85 - Investigating moving fluids or granular solids
86.
LUMINESCENT DIAMOND WITH NEGATIVELY CHARGED VACANCIES
Luminescent materials have red luminescent behavior after sintering using an HPHT process. Red luminescence is achieved with a temperature of 1475° C. to 1800° C. and potentially 1600° C. to 1750° C. with coarse sintered diamond powder having an average size greater than or equal to 100 nm. or more fine grain average grain sizes of at least 25 nm or at least 50 nm. The luminescent material has red luminescence as a result of NV− centers created through the HPHIT process which dominates over NV0 centers produced at lower temperatures. and over NVN centers produced at higher temperatures.
A chamber, e.g. in a heat exchanger or flowing electrolytic half-cell, for through flow of a fluid which is capable of elastic turbulence has an internal structure with obstructions to compel flow to undergo successive changes of direction thereby applying stress to the flow of fluid through the chamber. The internal structure comprises an upstream portion in which the applied stress induces elastic turbulence to begin and a downstream portion which applies less stress per unit length and sustains the elastic turbulence while providing economy of pressure to propel the fluid. Configuration of the upstream portion may be planned with computer modeling so as to avoid formation of stagnant zones.
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
H01M 10/6568 - Liquids characterised by flow circuits, e.g. loops, located externally to the cells or cell casings
88.
IN-SITU COMPOSITE POLYMERIC STRUCTURES FOR FAR-FIELD DIVERSION DURING HYDRAULIC FRACTURING
Methods include pumping a fracturing pad fluid into a subterranean formation under conditions of sufficient rate and pressure to create at least one fracture in the subterranean formation, the fracturing pad fluid including a carrier fluid and a plurality of bridging particles, the bridging particles forming a bridge in a fracture tip of a far field region of the formation. Methods further include forming a first plurality of fibers in situ into the subterranean formation to form a low permeability plug with the bridging particles, and pumping a proppant fluid comprising a plurality of proppant particles.
A method of predicting loading of a tool string implemented in a wellbore includes, for a formation testing operation of the wellbore, receiving temperature data for the wellbore and receiving pressure data for a fluid flowing through the tool string. The method includes, for the formation testing operation of the wellbore, estimating a deformation of the tool string based on the temperature data and the pressure data and based on physical properties of the tool string including determining thermal deformation of the tool string. The method further includes, for the formation testing operation of the wellbore, predicting one or more internal force of the tool string based on the deformation.
A system comprising a Wellhead equipment connected to a subsea wellhead via a tubing hanger, with a valve positioned within the tubing hanger, and a signal transmitter for transmitting a signal to the valve. If an "open" signal is transmitted by the signal transmitter, the valve activates an open position to allow flow within the Wellhead equipment. If a "close" signal is transmitted by the signal transmitter, the valve activates a close position to prevent flow within the Wellhead equipment. If no signal is received for a period of time, the valve activates a close position.
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
91.
RESISTIVITY IMAGING USING EM PROPAGATION MEASUREMENTS
Techniques and systems for generating resistivity images. A system includes an electromagnetic (EM) logging tool configured to generate EM propagation measurements during a drilling operation. The system also includes a processing system configured to be coupled to the EM logging tool, wherein the processing system is configured to calculate a resistivity image for a formation utilizing at least one EM propagation measurement of the EM propagation measurements and without use of an inversion technique or lookup table; and transmit the resistivity image for display on a display.
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
92.
SIDEWALL CORING TOOL FOR TESTING AND ESTIMATING ROCK PROPERTIES
Systems and methods presented herein include sidewall coring tools configured to perform testing on core samples and/or formations from which the core samples are extracted while collecting the core samples. For example, in certain embodiments, the sidewall coring tools may include downhole core laboratory having a plurality of testing modules configured to perform various testing procedures on core samples and/or formations from which the core samples are extracted while collecting the core samples. In addition, in certain embodiments, a testing module may include an inline scratcher device disposed in a travel path of the core samples during extraction of the core samples, which enable scratch testing to be performed on the core samples.
E21B 49/06 - 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 using side-wall drilling tools or scrapers
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
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
93.
RESISTIVITY IMAGING USING EM PROPAGATION MEASUREMENTS
Techniques and systems for generating resistivity images. A system includes an electromagnetic (EM) logging tool configured to generate EM propagation measurements during a drilling operation. The system also includes a processing system configured to be coupled to the EM logging tool, wherein the processing system is configured to calculate a resistivity image for a formation utilizing at least one EM propagation measurement of the EM propagation measurements and without use of an inversion technique or lookup table; and transmit the resistivity image for display on a display.
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
G01V 3/28 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
G01V 3/34 - Transmitting data to recording or processing apparatusRecording data
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
94.
ELECTRICALLY PATTERNED POLYCRYSTALLINE DIAMOND COMPACT FOR SENSING APPLICATIONS
A system includes an electrified polycrystalline diamond compact component. The electrified polycrystalline diamond compact component includes one or more graphene surfaces used to generate an electrical signal based on an applied pressure, an applied strain, an applied electrochemical potential, or an applied electromagnetic field, or a combination thereof.
G01L 1/22 - Measuring force or stress, in general by measuring variations in ohmic resistance of solid materials or of electrically-conductive fluidsMeasuring force or stress, in general by making use of electrokinetic cells, i.e. liquid-containing cells wherein an electrical potential is produced or varied upon the application of stress using resistance strain gauges
B23K 1/00 - Soldering, e.g. brazing, or unsoldering
A grout composition includes a grout binder comprising calcium sulfate, the grout binder constituting from about 25.0 weight percent to about 99.0 weight percent of the grout composition, and at least one thermal conductivity additive comprising graphite. A grout formed from the grout composition has a thermal conductivity greater than about 1.0 W/m·K. Related grout slurries formed from the grout composition, grouts, and methods of grouting a wellbore are also disclosed.
C04B 28/14 - 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 calcium sulfate cements
C04B 11/26 - Calcium sulfate cements starting from phosphogypsum or from waste, e.g. purification products of smoke
C04B 22/00 - Use of inorganic materials as active ingredients for mortars, concrete or artificial stone, e.g. accelerators
C04B 24/00 - Use of organic materials as active ingredients for mortars, concrete or artificial stone, e.g. plasticisers
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 tool capable of forming a seal includes a base, a member, and a seal member. The base includes an inner surface defining a bore configured to be in fluid communication with a well. The member is coupled to the base and rotatable relative to the base from a first position to a second position. The seal member includes an opening, a first end fixed to the member, and a second end fixed to the base. Rotation of the member from the first position to the second position rotates the first end relative to the second end to decrease a size of the opening.
A downhole tool for drilling a wellbore in a subterranean formation is described. The downhole tool includes a mounting block or chassis that experiences vibrations when drilling and at least one sensor or electronics assembly mechanically coupled to the mounting block or chassis by at least one vibration damper element.
A lock system includes a lock assembly for a movable component, a lock line configured to apply pressure to actuate the lock assembly, and a close line configured to apply pressure to close the movable component. The lock system also includes a pilot block with a respective pilot-operated check valve along the lock line, wherein the pilot block is actuated via a respective target pressure in the close line.
Methods of treating a subterranean formation are disclosed that include placing a treatment fluid into a subterranean formation, the treatment fluid containing a one or more polymers capable of consolidating to form a polymeric structure at a downhole location. Also disclosed are treatment fluids including a polymeric structure for treating a subterranean formation.
C09K 8/88 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
C09K 8/90 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
Techniques for determining trajectories for a plurality of wells while avoiding collision between wells are presented. The techniques can include determining a zone of uncertainty for individual wells of the plurality of wells, determining a minimum separation factor for individual wells of the plurality of wells, determining a gradient of a separation factor for at least one pair of wells of the plurality of pairs of wells, updating a nudge position for at least one well, and providing nudge positions for the individual wells of the plurality of wells.
