Methods and systems for operating automated unmanned aerial vehicles (UAVs) with self-diagnostics and immersive display. The method includes using one or more UAVs to obtain UAV survey data. The method further includes, for each of the one or more UAVs, obtaining UAV diagnostic data, determining at least one UAV action, executing the at least one UAV action, and transmitting the UAV survey data and the UAV diagnostic data to a UAV control station. The method further includes processing, using the UAV control station, the UAV survey data and the UAV diagnostic data forming processed UAV survey data and processed UAV diagnostic data, and transmitting, using the UAV control station, the processed UAV survey data and the processed UAV diagnostic data to an immersive display system. The method further includes displaying, using the immersive display system, at least, the processed UAV survey data and the processed UAV diagnostic data.
G05D 103/00 - Adaptations for complying with regulatory restraints on the operations of the controlled vehicles, e.g. compliance with airspace or traffic regulations
2.
METHOD FOR THE PREPARATION OF HEXAGONAL BORON-NITRIDE FROM AMMONIUM BORATE PRECURSORS
A method for preparing hexagonal boron-nitride includes processing a boron-containing aqueous solution, including introducing a water-soluble ammonium salt to the boron-containing aqueous solution, to obtain a processed solution, evaporating the processed solution to obtain a powder mixture, the powder mixture comprising ammonium borate and non-boron residues, and heat treating the powder mixture to obtain hexagonal boron nitride at a temperature in a range of 600 to 1000°C. A system includes a boron-containing aqueous solution source, at least one tank for boron-containing aqueous solutions, a first nitrogen source configured to introduce a water-soluble ammonium salt, a second nitrogen source that is different from the first nitrogen source configured to introduce ammonia gas, a solution evaporation system configured to hold at a temperature in a range of 50 to 300°C, and a powder heating system configured to hold at a temperature in a range of 600 to 1000°C.
Various embodiments provide systems that include an optical cable deployable in a wellbore. At least a first plasmonic element and a second plasmonic element are associated with the optical fiber cable at a first location and a second location, respectively. The system further includes an optical interrogator system configured to: transmit an outgoing light into the optical fiber cable; and receive an incoming light corresponding to the outgoing light.
E21B 47/135 - 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 using light waves, e.g. infrared or ultraviolet waves
G02B 6/30 - Optical coupling means for use between fibre and thin-film device
B82Y 20/00 - Nanooptics, e.g. quantum optics or photonic crystals
Apparatus, systems and methods for soil gas sampling are disclosed. The apparatus may include a first outer surface formed from a rigid liquid-impermeable and gas-impermeable material, and a second outer surface formed from an aquaphobic and gas-permeable membrane, where an edge of the second outer surface is attached to the first edge of the first surface, the first outer surface and the second outer surface entirely enclose an inner volume, and the second outer surface comprises a high specific surface area surface. The apparatus may further include a quantity of porous absorbing material, at least partially filling the inner volume, configured to preferentially absorb gaseous analytes.
Methods and systems are disclosed herein. A system may include a reconnaissance group comprising a first reconnaissance robot configured to perform reconnaissance for an acquisition area within the region of interest. The system may also include an acquisition group comprising a first acquisition robot configured to perform at least one of deploying, operating, and retrieving acquisition equipment within the acquisition area. The system may further include a central management system comprising a control processor configured to generate reconnaissance instructions for and receive reconnaissance information from the reconnaissance group and generate acquisition instructions for and receive acquisition information from the acquisition group. The system may include a communication system configured to communicate between the central management system and the reconnaissance group and the acquisition group.
An ion exchange resin includes a plurality of polymer resin particles which include a plurality of pores. The plurality of particles include an acid surface functionalization group and include a recycled thermoplastic polymer. A method for producing ion exchange resins includes dissolving a polymer and an emulsion stabilizer in a first solvent forming a dissolved polymer phase, mixing a removable matrix filler with the dissolved polymer phase to form a polymer mixture, forming an emulsion in a microfluidic device from the polymer mixture and a second solvent, precipitating a polymer composite which includes dispersed removable matrix fill in the microfluidic device, removing the dispersed removable matrix filler and forming precursor particles, and surface modifying the precursor particles, forming the ion exchange resin.
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
7.
METHOD AND SYSTEM FOR PRODUCTION OF PRODUCED WATER AND DESALINATION TREATMENT RESINS
An ion exchange resin includes a plurality of polymer resin particles which include a plurality of pores. The plurality of particles include an acid surface functionalization group and include a recycled thermoplastic polymer. A method for producing ion exchange resins includes dissolving a polymer and an emulsion stabilizer in a first solvent forming a dissolved polymer phase, mixing a removable matrix filler with the dissolved polymer phase to form a polymer mixture, forming an emulsion in a microfluidic device from the polymer mixture and a second solvent, precipitating a polymer composite which includes dispersed removable matrix fill in the microfluidic device, removing the dispersed removable matrix filler and forming precursor particles, and surface modifying the precursor particles, forming the ion exchange resin.
Methods and systems are disclosed. The methods may include obtaining a sonic data set. The method may define a three-dimensional ("3D") computational grid, wherein the 3D computational grid represents a geological volume. The method may further define at least one computational surface transecting the 3D computational grid. Using the 3D computational grid, the method may further comprise simulating forward-in-time propagation of a 3D source wavefield and simulating backward-in-time of a 3D receiver wavefield and storing a plurality of time snapshots of each wavefield at locations defined by the at least one computational surface. The method may include forming, using the sonic imaging system, a sonic image of the geological volume over each computational surface based on a combination of partial images formed from the snapshots.
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
9.
SYSTEMS AND METHODS FOR PREPARING A LITHOLOGICALLY BALANCED TRAINING SET
A method for training a machine learning engine from a balanced training set is provided. The method includes receiving a plurality of images of cuttings from a geological formation, generating a lithology vector associated with each image of the plurality of images to form an image/vector set comprising a plurality of image/vector pairs, the lithology vector comprising a plurality of rock types and a percentage of each of the plurality of rock types identified in a respective image, and balancing the image/vector set based on an occurrence of the plurality of rock types across the plurality of image/vector pairs to generate the balanced training set.
G06V 10/774 - Generating sets of training patternsBootstrap methods, e.g. bagging or boosting
G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
Systems and methods for inertial cavitation inception at high static pressures are disclosed. The methods may include installing an apparatus in a borehole, wherein the apparatus includes a cavitation chamber configured to enhance an amplitude of acoustic waves, an acoustic source configured to emit focused acoustic waves into the cavitation chamber, and a fluid channel configured to dispense a fluid into the cavitation chamber. The methods may further include activating the acoustic source in the cavitation chamber, dispensing the fluid into the cavitation chamber, and dispensing an epoxy resin into a fracture in the borehole.
Systems and methods for optimal reservoir model adaptation based on spatiotemporal well connectivity analysis are disclosed. The methods include obtaining production time-series data and metadata from a plurality of wells in a subsurface; preprocessing the production time-series data and the metadata; training a ML model with the preprocessed production time-series data and metadata; predicting a future production times series data with the ML model; determining well connectivity scores of a subsurface with the ML model; detecting a change in reservoir dynamics with a change point method; and modifying a well development plan based on the change in reservoir dynamics.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
A method for generating hydrogen includes oxidizing a natural polysaccharide included in a fracturing fluid in a subterranean formation, extracting the fracturing fluid from the subterranean formation, purifying the fracturing fluid, and treating the fracturing fluid. The method further includes introducing at least one additive into the fracturing fluid, introducing at least one microbial biomass into the fracturing fluid, and biodegrading the natural polysaccharide in the fracturing fluid with the at least one microbial biomass to produce hydrogen, reaction products and non-degrading products. A fluid composition includes a natural polysaccharide, at least one microbial biomass, an oxidizing agent, at least one additive, and a fluid medium. The microbial biomass includes a hydrogen-producing bacteria. A method for producing a fluid composition includes sequentially adding an oxidizing agent, an additive, and a microbial biomass to a source fracturing fluid. The source fracturing fluid includes a natural polysaccharide and a fluid medium.
C12P 3/00 - Preparation of elements or inorganic compounds except carbon dioxide
C08L 5/00 - Compositions of polysaccharides or of their derivatives not provided for in group or
C08J 3/205 - Compounding polymers with additives, e.g. colouring in the presence of a liquid phase
C09K 8/90 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
13.
SYSTEMS AND METHODS OF ACTIVATING LOSS CIRCULATION MATERIALS
A system for treating a lost circulation zone within a wellbore that includes a treatment sub 300 is provided. The treatment sub includes a communications device 336, an internal fluid conduit 1016 configured to convey a wellbore fluid through the treatment sub, and the interior 327 of the treatment sub 300 is between a sub exterior surface 328 and the internal fluid conduit 1016. The treatment sub 300 also includes a sonic frequency source 352 configured to generate a sonic frequency within a wellbore fluid. Further provided are methods of using the system to treat loss circulation zones.
Described is a method for detecting trace metal anomalies in soil. Soil samples are collected from an area of interest. The soil samples are prepared such that particle size and moisture content of each soil sample is normalized. An extraction solution having an amount of a carboxylic acid, an amount of a chelating agent, and an amount of a strong base is prepared. Using the extraction solution, a soil extract is obtained from each soil sample. Using a spectral instrument, a spectral analysis of each soil extract is performed to detect a chemical element. Based on the spectral analysis, presence of a hydrocarbon microseepage in the area of interest is determined.
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
15.
A METHOD FOR ACCELERATING NUMERICAL SOLUTION TO MULTIPHASE WELLBORE FLOW USING ARTIFICIAL INTELLIGENCE
A method for solving a multiphase fluid flow model with an iterative solver that is initialized using artificial intelligence. The method includes obtaining a set of equations, the set of equations including at least one equation, and the set of equations modeling a flow of a multiphase fluid, where the flow is characterized by a set of flow variables. The method further includes determining, with an artificial intelligence model, a predicted set of flow variables at a timestep given one or more prior sets of flow variables each previously determined at an associated prior timestep, and determining, with an iterative solver applied to the set of equations, the set of flow variables at the timestep, where the iterative solver is initialized with the predicted set of flow variables at the timestep.
A method of introducing cavitation downhole includes creating cavitation nuclei, introducing cavitation nuclei to a drilling fluid, delivering the drilling fluid downhole, and activating an acoustic source downhole. A method of preventing lost circulation includes introducing cavitation nuclei downhole, introducing lost circulation materials downhole where the lost circulation materials include a resin and microcapsules of a crosslinking agent, activating an acoustic source which may induce cavitation; and rupturing the microcapsules of the crosslinking agent to prevent lost circulation.
E21B 21/14 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using liquids and gases, e.g. foams
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
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
A system and method are described for making a proppant. The system includes a plurality of pumps for a first solution with an emulsion stabilizer, a matrix polymer, and a monomer; a second solution with an initiator, and a plant-based filler. The system includes a microfluidic device with a plurality of channels that receive the solutions, at least one channel junction where the solutions mix to form an emulsion, and a collecting zone. The process includes dissolving a matrix polymer, an emulsion stabilizer, and a monomer in a solvent to form a first solution and dissolving an initiator in another solvent to form a second solution, then adding a plant-based filler to the first or second solution, then feeding the solutions to a microfluidic device to form an emulsion, polymerizing the emulsion to form a proppant, and collecting the proppant.
A well treatment composition may include a capsule and a treatment agent solution within the capsule. The treatment agent solution may have a treatment agent. The system may include a radiation source: neutron, gamma, X-ray, and/or ultraviolet. A method may include introducing the well treatment composition downhole in wellbore circulation fluid, and introducing a radiation source into the wellbore and positioning the radiation source. The method may include activating the radiation source and emitting radiation that intermingles with the well treatment composition at a target location. The method may include maintaining the wellbore to allow emitted radiation from the activated radiation source to react with the well treatment composition, forming a radiation activated well treatment composition. The method may include allowing the radiation activated well treatment composition to disintegrate or dissolve, breaking encapsulation and releasing treatment agent at the target location.
C09K 8/92 - Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/88 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds
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
19.
SIMULTANEOUS DISTRIBUTED FIBER-OPTIC TELEMETRY AND SEISMIC ACQUISITION
Examples of methods and systems are disclosed. The methods may include detecting, using a plurality of autonomous seismic sensors, a first set of seismic signals. The methods may also include transmitting, by the autonomous seismic sensors, a plurality of encoded acoustic signals to a distributed acoustic sensing (DAS) system; wherein each encoded acoustic signal may include a representation of a seismic wave from the first set of seismic signals. The methods may further include detecting, using the DAS system, a superposition of the encoded acoustic signals and a second set of seismic signals. The methods still may further include determining, using a seismic processing system, the first set of seismic signals and the second set of seismic signals from the superposition. The methods may also include forming, using the seismic processing system, a seismic image from first set of seismic signals and the second set of seismic signals.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
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
G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
20.
METHOD FOR THE ESTIMATION OF ROCK MECHANICAL PROPERTIES USING DOWNHOLE MEASUREMENTS OF BOREHOLE OVALITY
A method for determining rock mechanical properties is disclosed. The method includes obtaining, at a selected depth location of a borehole, initial radial geometry measurements of the borehole and initial borehole fluid pressure measurements of a borehole fluid, perturbing a pressure of the borehole fluid, obtaining, in response to perturbing the pressure of the borehole fluid and at the selected depth location, dynamic radial geometry measurements of the borehole, analyzing a difference of the initial radial geometry measurements and the dynamic radial geometry measurements to determine differences in radial and axial components of strain tensor at a surface of the borehole at the selected depth location, determining the rock mechanical properties at the selected depth location by analyzing the differences in the radial and axial components of the strain tensor, and facilitating, based at least on the determined rock mechanical properties, a drilling operation of the subterranean formation.
A method may include determining various adaptive weights using a machine-learning model, first simulation data, and second simulation data. The method may further include determining predicted simulation data for a time step of the reservoir simulation using the adaptive weights, the first simulation data, the second simulation data, grid model data, and various reservoir simulation parameters. The method may further include determining whether the predicted simulation data satisfies a predetermined criterion. The method may further include determining, in response to determining that the predicted simulation data fails to satisfy the predetermined criterion, updated simulation data for the time step of the reservoir simulation based on the predicted simulation data, the grid model data, the reservoir simulation parameters, a search method, and the reservoir equations.
A microfluidic system (100) may include a set of replaceable microfluidic cartridges (3), each having a mechanically rigid box (202) and a set of parallel microfluidic capillaries (6), and a cooling system (216) that is in thermal contact with the mechanically rigid box (202). A gas stream may flow through the capillaries (6), and an aqueous fluid stream may flow through a space (5) in between an inner surface of the mechanically rigid box (202) and an outer surface of the set of capillaries (6). A method may include providing such a microfluidic system (100), introducing a gas stream through capillaries (6), introducing an aqueous fluid stream to flow through the space (5), generating gas bubbles (218) in the aqueous fluid stream through the capillaries (6), saturating the aqueous fluid stream with gas bubbles (218), recirculating the remaining undissolved gas through a dedicated contour tube and transferring the gas containing the aqueous fluid stream to an external storage unit.
A system includes: a plurality of syringe pumps that provide an aqueous solution including a stabilizer, a non-aqueous solution including a polymer dissolved in an organic liquid, and a curing agent; a microchannel network; and an evaporation unit that provides an elevated temperature so that the organic liquid in the emulsion evaporates and microcapsules form. The microchannel network includes: a plurality of channels that separately receive the aqueous solution and the nonaqueous solution from the syringe pumps; and at least one channel junction where the aqueous solution and the non-aqueous solution mix to form an emulsion. Each of the microcapsules has a shell including the polymer and a core including the curing agent.
B01J 13/20 - After-treatment of capsule walls, e.g. hardening
B01F 23/40 - Mixing liquids with liquidsEmulsifying
B81B 1/00 - Devices without movable or flexible elements, e.g. microcapillary devices
C09K 8/92 - Compositions for stimulating production by acting on the underground formation characterised by their form or by the form of their components, e.g. encapsulated material
24.
METHOD FOR OPTIMAL RESERVOIR MODEL ADAPTATION BASED ON SPATIOTEMPORAL WELL CONNECTIVITY ANALYSIS UTILIZING TIME DEPENDENT PRODUCTION DATA
Systems and methods for optimal reservoir model adaptation based on spatiotemporal well connectivity analysis are disclosed. The methods include obtaining production time-series data and metadata from a plurality of wells in a subsurface; preprocessing the production time-series data and the metadata; training a ML model with the preprocessed production time-series data and metadata; predicting a future production times series data with the ML model; determining well connectivity scores of a subsurface with the ML model; detecting a change in reservoir dynamics with a change point method; and modifying a well development plan based on the change in reservoir dynamics.
E21B 43/30 - Specific pattern of wells, e.g. optimising the spacing of wells
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
25.
MICROCAPSULES FOR WELL TREATMENT AND METHOD OF THEIR PRODUCTION
A well treatment composition includes a bio-based agent, a polymer shell encapsulating the bio-based agent, and a cationic macromolecule deposited on the polymer shell. A method for producing microcapsules containing a bio-based agent includes forming a first aqueous phase which includes a bio-based agent and a polymerization mixture, mixing the first aqueous phase with an oil phase at a junction producing emulsions, polymerizing the polymerization mixture to form a polymer shell encapsulating the bio-based agent, depositing a cationic macromolecule onto the polymer shell utilizing a second aqueous phase to form a microcapsule, and optionally post-treating the microcapsules with a post-treatment. A method for treating a formation includes introducing a well treatment composition into a wellbore, the well treatment composition adhering to downhole surfaces, releasing a bio-based agent from the well treatment composition, and the bio-based agent performing an intended action downhole.
C09K 8/536 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning characterised by their form or by the form of their components, e.g. encapsulated material
C09K 8/54 - Compositions for in situ inhibition of corrosion in boreholes or wells
C09K 8/582 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of bacteria
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 43/22 - Use of chemicals or bacterial activity
A system for autonomously deploying geophysical cables in sand dunes includes a surface station positioned at the sand dunes, one or more subsurface burrowing robots including distributed acoustic sensing geophysical cables laying robot, and a geo-locating radio system (GLRS). The one or more subsurface burrowing robots digs in the sand dunes to a target depth located between a base of the sand dunes and a base of loose sand, autonomously moves under a surface of the loose sand along a predefined path, exchanges data with the surface station via an unspooling cable, and receives commands from the surface station via the unspooling cable. The GLRS transmits telemetry data from the one or more subsurface burrowing robots to the surface station. The GLRS comprises a first GLRS positioned on the base of the sand dunes and a second GLRS disposed on the one or more subsurface burrowing robots.
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
H02G 9/02 - Installations of electric cables or lines in or on the ground or water laid directly in or on the ground, river-bed or sea-bottomCoverings therefor, e.g. tile
27.
GROUP OF UNMANNED AERIAL VEHICLES MISSION CONTROL SYSTEM FOR GEOPHYSICAL EXPLORATION
The invention refers to a system and a method for controlling a plurality of unmanned arial vehicles (UAV) and a non-transitory computer readable medium. The system comprises a processor and a transceiver to be accommodated on each of the plurality of UAVs and a control station. The method comprises transmitting to the plurality of UAVs, from the control station, input mission parameters for performing a task in an exploration area, including initial and target position of each UAV, determining, by the control station, an optimal flight path for each UAV, and generating a mission plan and flying paths for the plurality of UAVs where the plurality of UAVs does not collide with one another and with environmental obstacles. The invention provides increasing the efficiency of controlling a plurality of UAVs.
G05D 1/69 - Coordinated control of the position or course of two or more vehicles
G01V 3/16 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for use during transport, e.g. by a person, vehicle or boat specially adapted for use from aircraft
G05D 105/80 - Specific applications of the controlled vehicles for information gathering, e.g. for academic research
A method for determining multiphase flow rates using an economical flow meter, including receiving, for a period, observed data from a multiphase flow meter (MPFM) disposed on a pipeline carrying a multiphase fluid and determining first predicted data using a numerical simulator based on a wellbore model. The wellbore model is configured by a set of wellbore model configuration parameters. The method further includes calibrating the set of wellbore model configuration parameters based on the observed data and the first predicted data forming a set of calibrated wellbore model configuration parameters. The method further includes removing the MPFM and outfitting the pipeline with the economical flow meter, where the economical flow meter measures a total flow rate. The method further includes determining second predicted data using the numerical simulator with the wellbore model configured by the set of calibrated wellbore model configuration parameters and constrained by the total flow rate.
G01F 1/00 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow
E21B 47/003 - Determining well or borehole volumes
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
29.
METHOD AND APPARATUS FOR AUTONOMOUS GRAVITY AND/OR MAGNETIC FIELD MEASUREMENT
A measurement vehicle includes a geophysical sensor. One or more operational sensors are configured to detect operational data related to operation of the measurement vehicle. A driving system is configured to move the measurement vehicle in a travel direction relative to a measurement point. A controller is configured to receive information from the geophysical sensor and the operational sensors, and to control the driving system based on the information.
G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
B60F 5/02 - Other vehicles capable of travelling in or on different media convertible into aircraft
G01V 3/165 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for use during transport, e.g. by a person, vehicle or boat operating with magnetic or electric fields produced or modified by the object or by the detecting device
G01V 7/16 - Measuring gravitational fields or wavesGravimetric prospecting or detecting specially adapted for use on moving platforms, e.g. ship, aircraft
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
30.
METHODS AND SYSTEMS FOR DETECTING HYDROCARBON MICROSEEPAGE FROM DEEP GEOLOGICAL FORMATIONS
A method and system for determining a presence of a hydrocarbon microseepage based on an analysis of a dual soil sample is provided. The method may include collecting a dual soil sample from a borehole using a dual soil sampling system. The dual soil sample may include a soil sample collected with an active soil sampling device and a soil gas sample collected with an umbrella-shaped passive soil gas sampler. The method may further include determining an analysis of the dual soil sample using a dual soil sample processing system and determining a presence of the hydrocarbon microseepage based, at least in part, on the analysis.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
A method for training a machine learning engine from a balanced training set is provided. The method includes receiving a plurality of images of cuttings from a geological formation, generating a lithology vector associated with each image of the plurality of images to form an image/vector set comprising a plurality of image/vector pairs, the lithology vector comprising a plurality of rock types and a percentage of each of the plurality of rock types identified in a respective image, and balancing the image/vector set based on an occurrence of the plurality of rock types across the plurality of image/vector pairs to generate the balanced training set.
A method for automated text structuring for a cutting description document provides converting of the cutting description document from unstructured format to structured format more suitable for machine learning model training. In the method, a text from an unstructured cutting description document is read and parsed based on a dictionary file. Then, the parsed text is outputted to a structured document in a tabulated form. When a sentence in the text from the cutting description document includes a text in a mapping file, an associated text from the mapping file is outputted to the structured document in the tabulated form. When a word or phrase in the text from the cutting description document matches a text in a correction file, an associated text in the correction file is outputted to the structured document in the tabulated form.
A method to perform a field operation based on similarity of wells in a field is disclosed. The method includes generating, based on well log data files, a geology related similarity score for each pair of wells, generating, based on production data files, a production related similarity score for said each pair of wells, generating, by combining the geology related similarity score and the production related similarity score, a combined similarity score of said each pair of wells, determining, by aggregating the combined similarity score of said each pair of wells, an aggregate similarity score of each well, and facilitating, based at least on the aggregate similarity score of each well, the field operation in the field.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in 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
A microfluidic system (100) may include a set of replaceable microfluidic cartridges (3), each having a mechanically rigid box (202) and a set of parallel microfluidic capillaries (6), and a cooling system (216) that is in thermal contact with the mechanically rigid box (202). A gas stream may flow through the capillaries (6), and an aqueous fluid stream may flow through a space (5) in between an inner surface of the mechanically rigid box (202) and an outer surface of the set of capillaries (6). A method may include providing such a microfluidic system (100), introducing a gas stream through capillaries (6), introducing an aqueous fluid stream to flow through the space (5), generating gas bubbles (218) in the aqueous fluid stream through the capillaries (6), saturating the aqueous fluid stream with gas bubbles (218), recirculating the remaining undissolved gas through a dedicated contour tube and transferring the gas containing the aqueous fluid stream to an external storage unit.
A system includes a pipe, a multiphase fluid, and a measurement unit. The multiphase fluid is disposed within the pipe. The measurement unit is connected to the pipe and includes a cylindrical structure, a first magnet, a second magnet, a first coil, and a second coil. The cylindrical structure is submersed in the multiphase fluid and has a first end and a second end. The first magnet is connected to the first end of the cylindrical structure, and the second magnet is connected to the second end of the cylindrical structure. The first coil is wound around the outer circumferential surface of the pipe in a location corresponding to a location of the first magnet disposed within the orifice. The second coil is wound around the outer circumferential surface of the pipe in a location corresponding to a location of the second magnet disposed within the orifice.
E21B 47/10 - Locating fluid leaks, intrusions or movements
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
G01F 7/00 - Volume-flow measuring devices with two or more measuring rangesCompound meters
G01F 15/00 - Details of, or accessories for, apparatus of groups insofar as such details or appliances are not adapted to particular types of such apparatus
36.
METHOD AND APPARATUS FOR AUTONOMOUS GRAVITY AND/OR MAGNETIC FIELD MEASUREMENT
A measurement vehicle includes a geophysical sensor. One or more operational sensors are configured to detect operational data related to operation of the measurement vehicle. A driving system is configured to move the measurement vehicle in a travel direction relative to a measurement point. A controller is configured to receive information from the geophysical sensor and the operational sensors, and to control the driving system based on the information.
G01V 7/16 - Measuring gravitational fields or wavesGravimetric prospecting or detecting specially adapted for use on moving platforms, e.g. ship, aircraft
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
B60F 5/00 - Other vehicles capable of travelling in or on different media
37.
METHOD FOR DETERMINING PHYSICAL PROPERTIES OF ROCKS AND ROCK MATRIX
A method and a system for predicting physical properties of rock are disclosed. The method includes obtaining digital images of drill cuttings and data on drilling parameters and mud gas content and inputting of the obtained digital images of the drill cuttings to a first trained artificial intelligence model to determine the physical properties of a rock matrix and a lithological composition of the drill cuttings. The data on the lithological content of the drill cuttings, the drilling parameters, and the mud gas data are inputted to a second trained artificial intelligence model to determine a total porosity, an effective porosity, and a saturation of rocks. Additionally, the method includes inputting of the data on the total porosity, the effective porosity, and the saturation of the rocks, and the physical properties of the rock matrix to a rock-physics model to determine the physical properties of the rocks.
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
G01N 15/08 - Investigating permeability, pore volume, or surface area of porous materials
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
A system and method for using a Distributed Acoustic Sensor (DAS) system to receive signals transmitted from remote autonomous sensors and to locate the autonomous sensors are disclosed. The method includes installing a DAS system in a borehole consisting of at least one fiber-optic cable connected to at least one corresponding interrogator, deploying at least one autonomous sensor and conducting at least one measurement. The methods also include encoding the at least one measurement in at least one encoded acoustic signal, transmitting the at least one encoded acoustic signal to the at least one fiber-optic cable, and detecting the at least one encoded acoustic signal with the DAS system. Furthermore, the methods include recording the at least one encoded acoustic signal received by the DAS system at a surface location and processing the at least one encoded acoustic signal with a processing unit to decode and obtain the at least one measurement.
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
H04B 10/25 - Arrangements specific to fibre transmission
39.
SOURCE DETERMINATION OF PRODUCED WATER FROM OILFIELDS WITH ARTIFICIAL INTELLIGENCE TECHNIQUES
A method involving collecting a first geochemical data set for a first plurality of produced water samples; collecting a second plurality of produced water samples; performing geochemical analyses on the second plurality of produced water samples to form a second geochemical data set; and combining the first and second geochemical data sets into a database. The method further includes determining, by a subject matter expert, a water type for each produced water sample in the database and training a machine-learned model with the database to predict the water type of a produced water sample given its geochemical data. The method further includes collecting a third plurality of produced water samples, performing geochemical analysis on the third plurality of produced water samples, and determining, with the trained machine-learned model, the water type for each produced water sample in the third plurality of produced water samples using the third geochemical data set.
G01V 9/02 - Determining existence or flow of underground water
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
A composition that includes a fluorescent metal-organic framework (MOF) and a drilling fluid is provided. The MOF includes a porous, crystalline structure and a fluorescent source. A method includes introducing a MOF into a drilling fluid and circulating the drilling fluid through a well during a drilling operation that creates formation cuttings such that the fluorescent MOF interacts with the formation cuttings, creating tagged cuttings. The method further includes collecting returned cuttings from the circulating drilling fluid at a surface of the well, detecting the presence of the fluorescent MOF on the returned cuttings to identify the tagged cuttings, and correlating the tagged cuttings with a drill depth in the well at a time during the drilling operation.
A well treatment composition may include a capsule and a treatment agent solution within the capsule. The treatment agent solution may have a treatment agent. The system may include a radiation source: neutron, gamma, X-ray, and/or ultraviolet. A method may include introducing the well treatment composition downhole in wellbore circulation fluid, and introducing a radiation source into the wellbore and positioning the radiation source. The method may include activating the radiation source and emitting radiation that intermingles with the well treatment composition at a target location. The method may include maintaining the wellbore to allow emitted radiation from the activated radiation source to react with the well treatment composition, forming a radiation activated well treatment composition. The method may include allowing the radiation activated well treatment composition to disintegrate or dissolve, breaking encapsulation and releasing treatment agent at the target location.
A seismic drone, a system including a plurality of seismic drones and a base station, and a method of use of the system is disclosed. The seismic drone includes a positioning device, surveillance system, telecommunications transceiver, electronic control system (including a microprocessor), adaptable landing gear, a seismic receiver deployment system, and a seismic data recording system. The seismic drone is capable of take-off, flight to a target location (or locations), landing at the target location, deploying a seismic receiver, and sending data back to a base station or master drone.
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