Methods (and related apparatus) include obtaining data regarding a measured property. The measured property includes an amount of each of predetermined hydrocarbons in a gas sample extracted from drilling fluid exiting a wellbore having a hydrocarbon resource. An unknown characteristic of an investigated fluid property of the hydrocarbon resource is predicted utilizing the obtained input data and one or more predetermined models each built via statistical classification and regression analysis of a preexisting database containing records. Each record includes known characteristics of fluid properties of a different one of known reservoir fluids. The fluid properties include the investigated fluid property and the measured property. The investigated fluid property includes a fluid type of the hydrocarbon resource, an amount of at least one additional hydrocarbon, gas-oil ratio, or stock tank oil density.
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
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 method can include receiving well logs, as series data, for wells, where the well logs represent stratigraphic characteristics of a field; for each of the well logs, generating a corresponding vector representation in a dimensional space using a transformer encoder; and determining similarity of the well logs via their corresponding vector representations to characterize well log quality for well log correlation of the field.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
G01V 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
A system and method that may include receiving information and analyzing the information with respect to tiered well construction activities. The system and method may also include determining at least one constraint associated with the tiered well construction activities based on the information. The system and method may additionally include generating a workflow that includes at least a series of tiered well construction activities based on the at least one constraint. The system and method may further include generating a digital well plan that is to be executed to control field equipment to perform at least one of the series of tiered well construction activities of the workflow.
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
G05B 15/02 - Systems controlled by a computer electric
G06Q 10/0631 - Resource planning, allocation, distributing or scheduling for enterprises or organisations
H04L 67/125 - Protocols specially adapted for proprietary or special-purpose networking environments, e.g. medical networks, sensor networks, networks in vehicles or remote metering networks involving control of end-device applications over a network
4.
SYSTEMS AND METHODS FOR DETERMINING DEFORMATION OF A TOOL STRING
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 method for generating high-quality seismic data includes receiving a first dataset. The method also includes selecting a first processing technique based upon the first dataset. The method also includes producing first processed data from the first dataset using the first processing technique. The method also includes selecting a second processing technique based upon the first dataset. The second processing technique is different than the first processing technique. The method also includes producing second processed data from the first dataset using the second processing technique. The method also includes training a machine learning model to transform the first processed data into the second processed data.
The system and method in accordance with the present disclosure include an edge gateway to separate insecure protocols from the cloud and to securely transmit data to the cloud over a physical medium. Embodiments also include a virtual gateway that executes in a secure environment, and an adapter that enables a developer to have an endpoint to push data into an already segmented data area provided by the virtual gateway. The system and method allow a developer to publish data virtually to a data aggregator from a developer machine, or to publish data from a first gateway to a second virtual gateway to a data aggregator.
A method includes receiving at least one drilling condition input from at least one sensor of a drilling rig, obtaining a first slide mode determination based at least partially on a rotational speed of a drill string, obtaining a second slide mode determination based at least partially on torque applied to the drill string, selecting one of the first or second slide mode determinations based on the at least one drilling condition input, determining that the drilling rig is in slide mode based on the selected one of the first or second slide mode determinations, calculating at least one steering parameter based at least in part on determining that the drilling rig is in slide mode, and executing at least one drilling operation based in part on the at least one steering parameter.
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 scalable manifold assembly includes a header assembly configured to receive production fluid from one or more wells fluidly coupled to the header assembly and deliver process fluid to the one or more wells fluidly coupled to the header assembly and a frame assembly configured to at least partially surround the header assembly. The header assembly includes one or more header modules, the frame assembly includes one or more frame modules, the header assembly and the frame assembly are integrated together such that the frame assembly supports the header assembly, a quantity and type of the one or more frame modules corresponds to a quantity and type of the one or more header modules, and each of the one or more frame modules and the one or more header modules are scalable, repeatable, and configurable.
Certain embodiments of the present disclosure include a method that includes receiving data relating to a coiled tubing operation in substantially real time during the coiled tubing operation. The method also includes iteratively generating an estimated friction coefficient between coiled tubing and a wellbore within which the coiled tubing is disposed during the coiled tubing operation based at least in part on the data relating to the coiled tubing operation. The method further includes estimating one or more parameters of the coiled tubing operation during the coiled tubing operation based at least in part on the estimated friction coefficient.
A system for inspecting one or more gas plumes in a facility, including a processor and a memory having instructions executable by the processor, wherein the instructions are configured to obtain one or more images from one or more cameras, wherein the one or more images include a gas plume. The instructions are further configured to focus the one or more images on an area of interest with an object detection model to generate a boundary box around the gas plume, and focus the one or more images on the area of interest with a segmentation model to generate a mask around the gas plume based on the boundary box. The instructions are further configured to obtain one or more masked images from the segmentation model, and analyze the one or more masked images to obtain an image analysis of one or more parameters of the gas plume.
Embodiments presented provide for a quantification of mud properties used in hydrocarbon recovery operation. In certain embodiments, artificial intelligence and dielectric dispersion measurements are used for quantification of mud properties.
G01V 3/18 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging
G01N 27/22 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating capacitance
G01N 27/04 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance
A method for performing one or more capture utilization and sequestration (CCUS) operations. The method includes obtaining, from a vibration sensor, ambient noise data associated with a subsurface of a resource site. The method also includes generating, from the ambient noise data, passive virtual shot data indicating temporal properties or interactions present in the ambient noise data. The method also includes determining, using the passive virtual shot data, shot analysis data. The method also includes generating, using the shot analysis data, a model representing changes in past CCUS operations for the resource site. The method also includes initiating, based on the model, one or more additional CCUS operations for the resource site.
The system and method in accordance with the present disclosure include an edge gateway to separate insecure protocols from the cloud and to securely transmit data to the cloud over a physical medium. Embodiments also include a virtual gateway that executes in a secure environment, and an adapter that enables a developer to have an endpoint to push data into an already segmented data area provided by the virtual gateway. The system and method allow a developer to publish data virtually to a data aggregator from a developer machine, or to publish data from a first gateway to a second virtual gateway to a data aggregator.
A method comprising developing a near-wellbore reservoir model based on a logging-while-drilling (LWD) process in a wellbore, simulating mud-filtrate invasion in the near-wellbore reservoir model to obtain a simulated saturation and salinity distribution data, converting the simulated saturation and salinity distribution data to a resistivity distribution data, simulating azimuthal multi-depth-of-investigation (DOI) resistivity imaging data based on the resistivity distribution data, and performing an inversion on the azimuthal multi-DOI resistivity imaging data to infer invasion parameters.
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 47/002 - Survey of boreholes or wells by visual inspection
A method for predicting fluid properties includes measuring one or more measured fluid properties of a mud gas at a surface of a wellbore. The method also includes measuring one or more mud gas properties of the mud gas at the surface of the wellbore. The method also includes predicting one or more first predicted fluid properties using one or more pre-trained machine-learning (ML) models. The one or more first predicted fluid properties are predicted based at least partially upon the one or more mud gas properties. The method also includes comparing the one or more measured fluid properties to the one or more first predicted fluid properties. The method also includes re-training the one or more pre-trained ML models to produce one or more re-trained ML models in response to the comparison.
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
16.
ELECTRICAL ACCUMULATOR SYSTEM WITH INTERNAL TRANSFER BARRIER
A system includes a first accumulator system, a second accumulator system, an electronic module including a battery system, and a drilling component. The electronic module is electrically coupled to the first and second accumulator systems, and the drilling component is hydraulically coupled to the first and second accumulator systems.
A method includes receiving input data from external data sources. The input data is received by a data product pipeline. The method also includes extracting a portion of the input data using the data product pipeline to produce extracted data. The method also includes transferring the extracted data from the data product pipeline to a data product raw storage. The method also includes receiving the input data directly from the external data sources. The method also includes transferring the extracted data and the input data from the data product raw storage back to the data product pipeline. The method also includes receiving data products. The method also includes transforming the input data, the extracted data, and the data products into transformed data using the data product pipeline. The method also includes transferring the transformed data to a data product artifact storage.
The present disclosure provides systems and methods of forming a nickel composite. The method includes producing a semi-conductive component having a crystalline structure. A plurality of atomic layers of the semi-conductive component are exfoliated. At least a layer of a conductive component is disposed between each atomic layer of the plurality of atomic layers of the semi-conductive component.
H01M 4/48 - Selection of substances as active materials, active masses, active liquids of inorganic oxides or hydroxides
H01M 4/58 - Selection of substances as active materials, active masses, active liquids of inorganic compounds other than oxides or hydroxides, e.g. sulfides, selenides, tellurides, halogenides or LiCoFySelection of substances as active materials, active masses, active liquids of polyanionic structures, e.g. phosphates, silicates or borates
H01M 4/583 - Carbonaceous material, e.g. graphite-intercalation compounds or CFx
H01M 12/06 - Hybrid cellsManufacture thereof composed of a half-cell of the fuel-cell type and of a half-cell of the primary-cell type with one metallic and one gaseous electrode
19.
DETECTION AND QUANTIFICATION OF MULTIPLE METHANE LEAKS
Systems and methods are described for detecting multiple methane leaks at a site is provided. The method includes receiving methane concentration data from a network of methane sensors positioned at various locations within the site. The data is analyzed to identify elevated methane levels, and a multi-leak detection algorithm is applied to distinguish between multiple leak sources. Spatial distributions of methane concentrations are generated to designate potential leak regions. The method further includes estimating the locations of the leaks by identifying regions with the highest concentrations, and quantifying the uncertainty of the estimated leak locations using statistical models, such as Markov-Chain Monte Carlo (MCMC) methods. The system assigns a certainty level to each leak source and can display the leak locations and uncertainty values on a graphical interface. This method enhances methane leak detection in real-time and improves accuracy in attributing leak sources within complex industrial sites.
This disclosure generally relates to systems and methods for inspecting one or more equipment of a facility. The system may be configured to obtain one or more images including an equipment from one or more cameras, wherein the one or more cameras are fixed within the facility or are attached to an unmanned autonomous vehicle; focus the one or more images on an area of interest with an object detection model to generate a boundary box around the equipment; focus the one or more images on the area of interest with a segmentation model to generate a mask around the equipment based on the boundary box; obtain one or more masked images from the segmentation model; and analyze the one or more masked images to obtain an image analysis of one or more parameters of the equipment.
Techniques and systems for logging tool data channel prioritization. A system includes a logging tool configured to generate measurements in a well during a drilling operation and transmit a predetermined portion of the measurements and a processing system configured to be coupled to the logging tool, wherein the processing system is configured to calculate which data channels of the logging tool to prioritize as the predetermined portion of the measurements to transmit and transmit a control signal to configure the logging tool to transmit the predetermined portion of the measurements.
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
22.
MULTIFUNCTIONAL TREATMENT FLUID PACKAGES, AND RELATED TREATMENT FLUIDS AND METHODS
Certain embodiments of the present disclosure include techniques for preparing a multifunctional treatment fluid package and usage thereof in one or more wellsite operations. A method of providing a multifunctional treatment fluid package to a wellbore includes providing a multifunctional treatment fluid package to a wellsite, mixing the multifunctional treatment fluid package with a fluid to form a treatment fluid, and circulating the treatment fluid to a wellbore extending through a subterranean formation. The multifunctional treatment fluid package includes a friction reducer package, a biocide, and a scale inhibitor treatment fluids and multifunctional treatment fluid packages are also disclosed.
A method can include controlling a simulator to perform a simulation as to component interactions for gas and liquid components in a subsurface region; during the simulation, computing fugacity values using an equation of state, computing an equilibrium constant value using a first machine learning model, computing a Henry's law constant value using a second machine learning model, and computing component mole fraction values in a gas phase and in a liquid phase based on the fugacity values, the equilibrium constant value, and the Henry's law constant value; and generating simulation results for the subsurface region based at least in part on the component mole fraction values.
A method can include receiving input for a group of wells in a subsurface region, where the group of wells defines a hydraulically fractured production unit; predicting production data for the group of wells using a machine learning model; and outputting the predicted production data.
Systems and methods are described for an automatic and adaptive scanning method to efficiently scan for gas plumes using an imaging or LiDAR based gas monitoring system. In an example, the gas monitoring system can be coupled to a laser absorption spectroscopy with LiDAR. In an example, systems and methods for optimizing the utilization of the imaging or LiDAR based gas monitoring system includes planning, commissioning, acquiring data automatically, interpreting the data, or extracting gas emission events from the data, or a combination thereof, to provide a complete lifecycle of a gas leak and a comprehensive understanding of the gas emissions. In another example, systems and methods for detecting the presence of a plume of gas includes using supervised machine learning to train a model to recognize which images contain plumes of gas and estimate corresponding rates of gas leakage based on the images.
G01M 3/04 - Investigating fluid tightness of structures by using fluid or vacuum by detecting the presence of fluid at the leakage point
G01N 9/24 - Investigating density or specific gravity of materialsAnalysing materials by determining density or specific gravity by observing the transmission of wave or particle radiation through the material
Techniques and systems for logging tool data channel prioritization. A system includes a logging tool configured to generate measurements in a well during a drilling operation and transmit a predetermined portion of the measurements and a processing system configured to be coupled to the logging tool, wherein the processing system is configured to calculate which data channels of the logging tool to prioritize as the predetermined portion of the measurements to transmit and transmit a control signal to configure the logging tool to transmit the predetermined portion of the measurements.
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
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 3/34 - Transmitting data to recording or processing apparatusRecording data
27.
DRILLING PERFORMANCE ASSISTED WITH AN ARTIFICIAL INTELLIGENCE ENGINE
A method for extracting data from a database for use in a well construction process includes receiving a question from a user. The question is in a well construction language. The method also includes determining context based upon the question. Determining the context includes retrieving key performance indicators (KPIs) based upon the question, and retrieving a plurality of tables from the database. The tables are retrieved based upon the question. The method also includes generating a prompt based upon the question and the context. The method also includes generating a structured query language (SQL) query based upon the prompt using a large language model (LLM). The method also includes running the SQL query against the tables in the database in an attempt to produce a new table. The method also includes performing a wellsite action in response to the new table.
Described herein are methods of recovering lithium from dilute lithium sources. The methods include extracting lithium from an extraction feed using direct lithium extraction in an extraction stage to yield a lithium intermediate, performing one or more concentration operations, each concentration operation concentrating an input stream to yield an output feed, wherein the input stream is obtained from the lithium intermediate and/or the extraction feed is obtained from the output feed. At least one of the concentration operations includes a membrane separation operation having a plurality of reactors in series each having a semi-permeable membrane, such as a counter-flow reverse osmosis operation. Methods may also include generating a low TDS stream as a permeate from any of the one or more concentration operations, wherein the low TDS stream is recycled or used as fresh water.
B01D 45/16 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces generated by the winding course of the gas stream
A system includes one or more sensors to obtain three-dimensional (3D) data in a facility and a processor communicatively coupled to the one or more sensors. The processor is configured to execute instruction to generate a 3D model of the facility based on a first 3D data received from the one or more sensors at a first time and receive a second 3D data from the one or more sensors at a second time after the first time. The processor is further configured to execute instructions to determine an event based on the second 3D data and the 3D model and output a notification via an electronic device based on the event.
G01S 17/89 - Lidar systems, specially adapted for specific applications for mapping or imaging
G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
G06V 20/40 - ScenesScene-specific elements in video content
G06V 20/52 - Surveillance or monitoring of activities, e.g. for recognising suspicious objects
30.
SYSTEMS AND METHODS FOR THERMAL INSPECTION OF EQUIPMENT USING OBJECT DETECTION AND SEGMENTATION MODELS
This disclosure generally relates to systems and methods for inspecting one or more equipment of a facility. The system may be configured to obtain one or more images including an equipment from one or more cameras, wherein the one or more cameras are fixed within the facility or are attached to an unmanned autonomous vehicle; focus the one or more images on an area of interest with an object detection model to generate a boundary box around the equipment; focus the one or more images on the area of interest with a segmentation model to generate a mask around the equipment based on the boundary box; obtain one or more masked images from the segmentation model; and analyze the one or more masked images to obtain an image analysis of one or more parameters of the equipment.
G06V 20/17 - Terrestrial scenes taken from planes or by drones
G06V 20/52 - Surveillance or monitoring of activities, e.g. for recognising suspicious objects
H04N 23/23 - Cameras or camera modules comprising electronic image sensorsControl thereof for generating image signals from infrared radiation only from thermal infrared radiation
31.
SYSTEMS AND METHODS FOR INSPECTION OF GAS PLUME USING OBJECT DETECTION AND SEGMENTATION MODELS
A system for inspecting one or more gas plumes in a facility, including a processor and a memory having instructions executable by the processor, wherein the instructions are configured to obtain one or more images from one or more cameras, wherein the one or more images include a gas plume. The instructions are further configured to focus the one or more images on an area of interest with an object detection model to generate a boundary box around the gas plume, and focus the one or more images on the area of interest with a segmentation model to generate a mask around the gas plume based on the boundary box. The instructions are further configured to obtain one or more masked images from the segmentation model, and analyze the one or more masked images to obtain an image analysis of one or more parameters of the gas plume.
Embodiments presented provide for a method of obtaining an accurate wellbore response using a dual packer system. In embodiments, a wellbore in-situ environment is cleaned prior to obtaining a fluid sample for fluid analysis. The method may include inflating the dual packer to an initial pressure, determining if the dual packer is fully set, and stopping the method when the dual packer is fully set. The method may include measuring a volume of fluid within the dual packer, pumping a fluid in an isolation zone between the dual packer, measuring a volume of the fluid pumped from the isolation zone, measuring a pressure for the dual packer, measuring a pressure interval, and determining if the volume of fluid has reached a threshold and when the volume of fluid has reached the threshold to determine the existence and condition of a mud cake.
A metal-organic framework (MOF) may include a body including a MOF crystal having a composition selected to selectively extract one or more elements of interest from an aqueous solution. The MOF may include a plurality of MOF crystals bound by a bonding agent.
B01J 20/22 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising organic material
Described herein are methods of recovering lithium from dilute lithium sources. The methods include extracting lithium from an extraction feed using direct lithium extraction in an extraction stage to yield a lithium intermediate, performing one or more concentration operations, each concentration operation concentrating an input stream to yield an output feed, wherein the input stream is obtained from the lithium intermediate and/or the extraction feed is obtained from the output feed. At least one of the concentration operations includes a membrane separation operation having a plurality of reactors in series each having a semi-permeable membrane, such as a counter-flow reverse osmosis operation. Methods may also include generating a low TDS stream as a permeate from any of the one or more concentration operations, wherein the low TDS stream is recycled or used as fresh water.
An system, including a first subsea electric subsystem, a first energy storage device associated with and directly coupled to the first subsea electric subsystem, a second subsea electric subsystem, a second energy storage device associated with and directly coupled to the second subsea electric subsystem, and a conduit coupled to the first energy storage device and coupled to the second storage device, wherein the first energy storage device is indirectly coupled to the second energy storage device via the conduit.
H02J 3/28 - Arrangements for balancing the load in a network by storage of energy
H02J 3/38 - Arrangements for parallelly feeding a single network by two or more generators, converters or transformers
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
36.
DRILLING FLUIDS INCLUDING A VISCOSIFIER, AND RELATED METHODS
A drilling fluid for drilling a subterranean wellbore includes water, salt, and a viscosifier comprising a first component comprising a reaction product of at least one acrylamide monomer and at least one sulfonated anionic monomer, and a second component comprising styrene-butadiene polymer. Related methods of operating a wellbore and drilling fluids are claimed.
An IPO gas lift valve. The IPO gas lift valve may include a dome assembly, a bellows system coupled to the dome assembly, a valve assembly, and a check valve assembly coupled to the valve assembly. The bellows system may include a liquid-filled scaled chamber, a piston positioned within the sealed chamber and dividing the sealed chamber into a dome side and a valve side, a first bellows assembly positioned within the dome side of the sealed chamber, and a second bellows assembly positioned within the valve side of the sealed chamber. The valve assembly may be operable to shift the IPO gas lift valve between an open position and a closed position.
A method for extracting data from a database for use in a well construction process includes receiving a question from a user. The question is in a well construction language. The method also includes determining context based upon the question. Determining the context includes retrieving key performance indicators (KPIs) based upon the question, and retrieving a plurality of tables from the database. The tables are retrieved based upon the question. The method also includes generating a prompt based upon the question and the context. The method also includes generating a structured query language (SQL) query based upon the prompt using a large language model (LLM). The method also includes running the SQL query against the tables in the database in an attempt to produce a new table. The method also includes performing a wellsite action in response to the new table.
A wellbore fluid includes a base fluid and a swellable fluid loss material comprising core-shell polymer particles. The core-shell polymer particles include a core comprising a nanoparticle, and a shell comprising a polymer coupled to the core, the polymer comprising at least one of a reaction product of acrylamide and 2‑acrylamido-2-methyl-propanesulfonic acid crosslinked with methylene bisacrylamide and tetra ethylene glycol diacrylate, a polyamine, a polyol, a polyvinyl ester, styrene-butadiene rubber, or polymethylmethacrylate. Related methods of operating a wellbore and wellbore fluids are disclosed.
C09K 8/76 - Eroding chemicals, e.g. acids combined with additives added for specific purposes for preventing or reducing fluid loss
C09K 8/70 - Compositions for forming crevices or fractures characterised by their form or by the form of their components, e.g. foams
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
E21B 43/26 - Methods for stimulating production by forming crevices or fractures
40.
DRILLING FLUIDS INCLUDING A VISCOSIFIER, AND RELATED METHODS
A drilling fluid for drilling a subterranean wellbore includes water, salt, and a viscosifier comprising a first component comprising a reaction product of at least one acrylamide monomer and at least one sulfonated anionic monomer, and a second component comprising styrene-butadiene polymer. Related methods of operating a wellbore and drilling fluids are disclosed.
C09K 8/42 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C04B 28/00 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
42.
GEOMETRY DESIGN FOR ACQUIRING SURFACE DAS DATA TO MONITOR CARBON STORAGE SITES
The disclosed method includes: determining a subsurface space of interest; arranging a source sensor array relative to a receiver sensor array of a Surface Distributed Acoustic Sensing (S-DAS); transmitting, from the source sensor array, a first set of seismic signals indicating baseline measurements; receiving, using the receiver sensor array, the baseline measurements and thereby generate baseline data; injecting fluid into the subsurface space of interest; transmitting, using the source sensor array, a second set of seismic signals indicating fluid plume measurements; receiving, using the receiver sensor array, the fluid plume measurements and thereby generate fluid plume data; determining, based on the baseline data and the fluid plume data, time-shift data and thereby generate fluid plume extent data; formatting the fluid plume extent data into data values that characterize an extent or rate of spread of the fluid plume; and visualizing the extent or rate of spread of the fluid plume.
A system includes a subsea geothermal power system. The subsea geothermal power system includes a well connection configured to couple to a hydrocarbon well. The subsea geothermal power system also includes a geothermal power plant fluidly coupled to the well connection. The geothermal power plant is configured to receive thermal energy from a well fluid received from the hydrocarbon well and convert the thermal energy into at least one of electrical energy and mechanical energy. The system also includes a subsea equipment at least partially powered by at least one of the electrical energy and the mechanical energy produced by the subsea geothermal power system.
F03G 4/00 - Devices for producing mechanical power from geothermal energy
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
44.
GEOTHERMAL POWER SYSTEMS AND METHODS FOR SUBSEA SYSTEMS
A system includes a subsea geothermal power system. The subsea geothermal power system includes a plurality of well connections configured to couple to a plurality of geothermal wells. The subsea geothermal power system also includes a geothermal power plant fluidly coupled to the plurality of well connections. The geothermal power plant is configured to receive thermal energy from the plurality of geothermal wells and convert the thermal energy into at least one of electrical energy and mechanical energy. The system also includes a subsea station having one or more pumps, one or more compressors, one or more separators, one or more energy storage devices, or a combination thereof. The subsea station is at least partially powered by the at least one of electrical energy and mechanical energy produced by the subsea geothermal power system.
F03G 4/02 - Devices for producing mechanical power from geothermal energy with direct fluid contact
F03G 4/00 - Devices for producing mechanical power from geothermal energy
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
45.
GEOTHERMAL POWER SYSTEMS AND METHODS FOR SUBSEA SYSTEMS
A system includes a subsea geothermal power system. The subsea geothermal power system includes a separator configured to separate a well fluid from a hydrocarbon well into a first fluid flow and a second fluid flow. The subsea geothermal power system also includes a geothermal power plant coupled to the separator. The geothermal power plant is configured to receive thermal energy from the second fluid flow and convert the thermal energy into at least one of electrical energy and mechanical energy. The separator is at least partially powered by the at least one of electrical energy and mechanical energy produced by the subsea geothermal power system.
F03G 4/00 - Devices for producing mechanical power from geothermal energy
E21B 43/01 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells specially adapted for obtaining from underwater installations
F03G 4/02 - Devices for producing mechanical power from geothermal energy with direct fluid contact
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
F24T 10/20 - Geothermal collectors using underground water as working fluidGeothermal collectors using working fluid injected directly into the ground, e.g. using injection wells and recovery wells
46.
PANORAMIC IMAGES FOR IMPROVED METHANE CAMERA COMMISSIONING, INTERPRETATION, AND REMOTE OPERATION
Example embodiments provide a method for improved commissioning, interpretation, and automated or remote operation of a methane density camera designed for monitoring of gas emissions. In some embodiments, the method consists of three related but independent steps including commissioning, remote operation, and data interpretation.
Systems and methods are described for calibrating an imaging or LIDAR based gas monitoring system for efficiently scanning for gas plumes. In an example, a calibration workflow that improves the accuracy of transformations from observed points in a particular camera frame to a coordinate system that is fixed with respect to the ground, such as a set of latitude, longitude, and height values; or a spherical polar coordinate system centered at the camera where the zenith is perpendicular to the ground.
48.
A METHOD TO REDUCE WATER UTILIZATION AND CARBON DIOXIDE EMISSIONS DURING STIMULATION OF A WELLBORE DURING HYDROCARBON RECOVERY OPERATIONS
Embodiments presented provide for a method to reduce water utilization in industrial processes. Example embodiments provide reduction of both water utilization and carbon dioxide emissions during stimulation procedures during hydrocarbon recovery operations.
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
G01V 3/32 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
49.
MACHINE-LEARNING BACKBONE MODEL FOR FRACTURE DESIGN
Systems and methods presented herein are configured to generate a machine-learning (ML) backbone model for generating a fracture design output to adjust operations associated with well stimulation, fracturing, and the like. A method may include generating a synthetic physics-based dataset for hydraulic fracturing or stimulation to use machine learning or predictive modeling. The method may also include generating a machine-learning (ML) model using the synthetic physics-based dataset. The method may also include combining a real fracturing dataset with the synthetic physics-based dataset and retrain ML model using a transfer learning approach. Further, the method may include adjusting a hydraulic fracturing operation, a stimulation operation, or both, using the ML model.
A method for operating an unmanned autonomous vehicle includes autonomously maneuvering the unmanned autonomous vehicle about a facility, collecting gas concentration data using one or more sensors carried on or integrated with the unmanned autonomous vehicle, monitoring the collected gas concentration data to detect a high concentration due to a gas leak. The method further includes, if a high concentration is detected, estimating a location of the gas leak and maneuvering the unmanned autonomous vehicle toward the estimated location of the gas leak.
G05D 1/689 - Pointing payloads towards fixed or moving targets
G01N 1/00 - SamplingPreparing specimens for investigation
G05D 105/85 - Specific applications of the controlled vehicles for information gathering, e.g. for academic research for patrolling or reconnaissance for police, security or military applications
G05D 105/80 - Specific applications of the controlled vehicles for information gathering, e.g. for academic research
G05D 107/70 - Industrial sites, e.g. warehouses or factories
Systems and methods of the present disclosure provide systems and methods for receiving one or more sets of parameters related to an operation corresponding to a wellbore. At a first time, the operation is simulated using the one or more sets of parameters and at least one simulator. Pertinent results from the simulation are recorded and stored in a table. The pertinent results include at least one constraint. At a second time, the constraint is retrieved from the table for performance of the operation, and the constraint is used to control the operation.
Systems and methods of the present disclosure include receiving measured data corresponding to a wellbore and locating the measured data in a flow map corresponding to the wellbore. The method also includes converting the measured data to determine friction loss and comparing the located measured data and the determined friction loss. Moreover, the method also includes determining that the located measured data is consistent with the determined friction loss with a common flow regime and deeming the common flow regime as a current flow regime. Furthermore, the method includes controlling an operation in the wellbore based at least in part on the deemed current flow regime.
E21B 47/10 - Locating fluid leaks, intrusions or movements
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
G01V 5/04 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
A multiple segment production assembly for subsurface wells, namely, flow control valves, subsurface safety valves, gas lift valves, packers, monitoring and telemetry equipment for segmenting a downhole well and enhancing control and monitoring of each individual segment while producing the well.
A method for determining a maximum tripping velocity for tripping a downhole tool string in a wellbore includes obtaining contextual data including wellbore data, tool string data, and drilling fluid data; computing downhole drilling fluid pressures at multiple tool string velocities and accelerations using the obtained contextual data and a wellbore hydraulics model; generating an equivalent circulation density (ECD) contour along a two-dimensional acceleration and velocity parameter space from the computed downhole drilling fluid pressures; and evaluating the ECD contour with at least one of a formation pore pressure or a formation fracture pressure to generate the maximum tripping velocity.
A system includes an interconnection terminal box connected to a plurality of core components in an integrated system. Through disconnection of one or more core components of the plurality of core components from the interconnection terminal box, the system is configured to individually test a at least one core component of the plurality of core components that remains connected to the interconnection terminal box, and through connection of the plurality of core components to the interconnection terminal box, the system is configured to test the integrated system as a whole.
Embodiments presented provide for a characterization of water-oil mixtures. In embodiments, electrical conductivity measurements are used to characterize water-oil mixtures.
Geopolymeric compositions are presented that are useful as geopolymer slurries for cementing subterranean wells. The slurries may contain an aluminosilicate source, an alkaline source and a carrier fluid. The slurries generate an alkali metal or alkaline earth hydroxide activator in situ, thereby avoiding or reducing handling of alkali materials at a wellsite.
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C04B 28/00 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
Geopolymer precursor compositions are presented that are useful for cementing a subterranean well, among other uses. The precursor compositions are dry mixtures that have an aluminosilicate source and an activator. The activator is an alkalinity source that is safe to store, transport, and blend with an aluminosilicate source. The activator may be a hydroxide-free activator. A geopolymer slurry is formed by adding water to the dry geopolymer precursor compositions. Such slurries have suitable characteristics for use in cementing applications that use pumpable mixtures.
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 22/10 - Acids or salts thereof containing carbon in the anion, e.g. carbonates
C04B 24/38 - Polysaccharides or derivatives thereof
C04B 28/00 - Compositions of mortars, concrete or artificial stone, containing inorganic binders or the reaction product of an inorganic and an organic binder, e.g. polycarboxylate cements
A technique facilitates long-term operation of a submersible pump which may be used in an electric submersible pumping system. According to an embodiment, the submersible pump comprises at least one stage, e.g. a plurality of stages. Each stage uses an impeller which may be rotated within a diffuser to establish a fluid flow through the pump. Additionally, each stage comprises an erosion control system positioned between the impeller and the diffuser to reduce erosion and/or the effects of erosion so as to extend the life of the submersible pump.
A metal-organic framework (MOF) may include a body including a MOF crystal having a composition selected to selectively extract one or more elements of interest from an aqueous solution. The MOF may include a plurality of MOF crystals bound by a bonding agent.
B01J 20/22 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof comprising organic material
B01D 15/20 - Selective adsorption, e.g. chromatography characterised by constructional or operational features relating to the conditioning of the sorbent material
B01J 20/28 - Solid sorbent compositions or filter aid compositionsSorbents for chromatographyProcesses for preparing, regenerating or reactivating thereof characterised by their form or physical properties
Branched and crosslinked polymeric fluid loss control agents and methods are provided that have at least one acrylamide-based monomer, at least one sulfonated anionic monomer, and at least one crosslinking monomer. The at least one acrylamide-based monomer and the at least one sulfonated anionic monomer are crosslinked. The branched and crosslinked polymeric fluid loss control agents have between 50 and 99 mol % of the at least one acrylamide-based monomer, between 1 and 30 mol % of the at least one sulfonated anionic monomer, and between 0.1 and 10 mol % of the at least one crosslinking monomer.
Systems and methods are described for identifying and validating a fugitive gas leak. The system identifies the onset of a leak, tracks its persistence, and subsequently, notes its gradual disappearance after repairs are initiated. The method comprises initiating an observation period which serves to characterize the behavior of the anticipated leak if it exists. Extracting the underlying distributions of the parameter space for the anticipated leak over an observation period. Data is collected over incremental steps and compared to the current reference distributions. When the test period is complete, the observation window is moved forward to include the data over the validation span. The procedure thus repeats, with an updated reference distribution and re-initialized validation period.
G01D 1/14 - Measuring arrangements giving results other than momentary value of variable, of general application giving a distribution function of a value, i.e. number of times the value comes within specified ranges of amplitude
G01M 3/02 - Investigating fluid tightness of structures by using fluid or vacuum
G01P 5/00 - Measuring speed of fluids, e.g. of air streamMeasuring speed of bodies relative to fluids, e.g. of ship, of aircraft
G01P 13/00 - Indicating or recording presence or absence of movementIndicating or recording of direction of movement
63.
SELF-CONSISTENT FLOW REGIME IDENTIFICATION FOR DOWNHOLE MONITORING
Systems and methods of the present disclosure include receiving measured data corresponding to a wellbore and locating the measured data in a flow map corresponding to the wellbore. The method also includes converting the measured data to determine friction loss and comparing the located measured data and the determined friction loss. Moreover, the method also includes determining that the located measured data is consistent with the determined friction loss with a common flow regime and deeming the common flow regime as a current flow regime. Furthermore, the method includes controlling an operation in the wellbore based at least in part on the deemed current flow regime.
A packer includes a cylinder of elastomer including: two flat ends, a longitudinal axis, an opening formed along the longitudinal axis, the opening configured to accommodate a cable, and at least one contact pressure feature running around a circumference of the cylinder. The cylinder is split perpendicular to the flat ends into two halves.
Cementing compositions contain water, a cement and an additive for adjusting thermal conductivity. The additive for adjusting thermal conductivity may be graphite, graphene, aluminum oxide, hematite, copper metal, copper oxide, aluminum, amorphous carbon, gallium metal, iron metal, magnesium oxide, nickel metal, nickel oxide, tin metal, tin oxide, zinc metal or zinc oxide, or combinations thereof. Such compositions may have thermal conductivities exceeding 2 W/mK. Such compositions may be useful in closed loop geothermal completions or for encasing electrical cables.
C04B 111/00 - Function, property or use of the mortars, concrete or artificial stone
C09K 5/14 - Solid materials, e.g. powdery or granular
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
A system and method for producing hydrocarbons from a well with a dual sleeve valve assembly. The dual sleeve valve assembly has a toe valve assembly and a production assembly. The toe valve assembly has a valve sleeve positioned in a valve housing comprising at least one fracturing port. The valve sleeve is shiftable to allow fluid through the least one fracturing port. The production assembly comprises a production sleeve positioned within a production outer housing comprising at least one screen port and at least one production port. A sand screen assembly disposed around the production outer housing. The production sleeve shiftable by a ball to allow fluid through the at least one screen port and the at least one production port.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 34/06 - Valve arrangements for boreholes or wells in wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
Described herein are implosion devices for use in a subterranean setting. These implosion devices use no explosives, and so create no combustion products within the subterranean environment. These implosion devices also capture all material used to create the implosion for easy removal from the subterranean environment. The implosion devices generally have an implosion chamber, a stretchable sleeve surrounding the implosion chamber, and a non-explosive initiator for imploding the implosion chamber.
E21B 37/08 - Methods or apparatus for cleaning boreholes or wells cleaning in situ of down-hole filters, screens, or gravel packs
E21B 27/00 - Containers for collecting or depositing substances in boreholes or wells, e.g. bailers for collecting mud or sandDrill bits with means for collecting substances, e.g. valve drill bits
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
68.
NANODIAMOND WITH VACANCY DEFECT AND QUANTUM DOT LUMINESCENCE
Luminescent diamond is made by subjecting a volume of diamond grains to high-pressure/high-temperature conditions with or without a catalyst or pressure transfer media to cause the grains to undergo plastic deformation to produce internal vacancy defects, increasing the luminescent activity/intensity of the resulting diamond material. The luminescent material is then subjected to further treatment to create quantum dots on the surface of the diamond particles. Quantum dot formation can include placing the diamond particles in liquid and subjecting the particles to laser pulses. The consolidated diamond material may be treated to further increase luminescent activity/intensity including reducing the consolidated diamond material to diamond particles, heat treatment in vacuum, and/or air heat treatment. The resulting luminescent diamond particles display a level of luminescence intensity greater than that of conventional luminescent nanodiamond, and may be functionalized for use in biological applications.
A method of operating a ground-source heat pump includes generating a thermal power based on a thermal communication of the ground-source heat pump with a borefield, the thermal power at least partly covering a thermal load of a facility. The method includes receiving a temperature associated with the borefield and controlling the thermal power based on the temperature. The method further includes maintaining the temperature within a temperature range based on controlling the thermal power, wherein the ground-source heat pump is configured to cause the temperature to fall outside of the temperature range at a full capacity of the thermal power.
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
70.
SYSTEMS AND METHODS FOR GAS LEAK DETECTION USING UNMANNED AUTONOMOUS VEHICLES
A method of operation of an unmanned autonomous vehicle includes autonomously maneuvering the unmanned autonomous vehicle about a facility, collecting gas concentration data using one or more sensors carried on or integrated with the unmanned autonomous vehicle, and monitoring the collected gas concentration data to detect a high concentration due to a gas leak. The method further includes, if a high concentration is detected, estimating a location of the gas leak and maneuvering the unmanned autonomous vehicle toward the estimated location of the gas leak.
A method of detecting wear of a downhole tool implemented in a subject wellbore includes receiving offset wellbore data for one or more offset wellbores and, based on the offset wellbore data, determining an expected downhole tool index for the downhole tool at one or more measurement depths including an active measurement depth of the subject wellbore. The method further includes receiving subject wellbore data and, based on the subject wellbore data, determining a subject downhole tool index in real time for the downhole tool at the active measurement depth. The method further includes determining the wear of the downhole tool based on comparing the subject downhole tool index to the expected downhole tool index at the active measurement depth in real time.
E21B 21/12 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using drilling pipes with plural fluid passages, e.g. closed circulation systems
E21B 45/00 - Measuring the drilling time or rate of penetration
72.
SOLVENT SYSTEMS FOR CARBON DIOXIDE CAPTURE AND METHODS OF MAKING AND USING SAID SYSTEMS
Amine-based solvents, carbon dioxide capture systems, and methods for improving stability of carbamate during carbon dioxide capture are disclosed herein. The amine-based solvents comprise at least one cyclic amine having a first molecular site that is structurally modified to be protonated and a second molecular site that is structurally modified to hold carbon dioxide as carbamate. The carbon dioxide capture systems comprise at least one gaseous stream comprising carbon dioxide and the amine-based solvent in contact with the at least one gaseous stream. The methods for carbon dioxide capture comprise contacting at least one modified cyclic amine to a gaseous stream comprising carbon dioxide such that the modified at least one cyclic amine chemically reacts with carbon dioxide to form a soluble compound.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A system for generating electrical power may include a flowline having an inlet that receives reservoir fluid at a first pressure, an outlet that outputs the reservoir fluid at a second pressure, a first flow path between the inlet and the outlet, and a second flow path between the inlet and the outlet, in parallel with the first flow path. The difference between the first pressure and the second pressure may include a pressure differential, and the system may include a valve that adjusts the pressure differential. Additionally, the system may include a turbine disposed along the second flow path that generates mechanical energy from a flow of the reservoir fluid induced by the pressure differential, and the mechanical energy may be converted to electrical energy.
F03G 7/04 - Mechanical-power-producing mechanisms, not otherwise provided for or using energy sources not otherwise provided for using pressure differences or thermal differences occurring in nature
E21B 41/00 - Equipment or details not covered by groups
74.
HYBRID CARBON CAPTURE SYSTEM WITH SORBENT CAPTURE STATE
A first subsystem receives a gas flow comprising a first concentration of carbon dioxide. The first subsystem separates the gas flow into a rich stream and a lean stream by a first carbon capture process. The rich stream includes a second concentration of carbon dioxide greater than the first concentration. The lean stream includes a third concentration of carbon dioxide less than the first concentration. A second subsystem receives the lean stream from the first subsystem. A carbon adsorption system removes at least a portion of the carbon dioxide from the rich stream, resulting in a depleted stream. A flow separator separates the depleted stream into a stack stream and a recycling stream. A carbon desorption system releases the portion of the carbon dioxide into the recycling stream. The recycling stream is directed to mix with at least one of the gas flow or the rich stream.
B01D 53/22 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by diffusion
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 53/04 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by adsorption, e.g. preparative gas chromatography with stationary adsorbents
Well spacer materials containing a small amount of cement raw material are used to precede pumping cement precursors into a well. Use of cement raw material in the spacer material reduces hardening loss in the cement at the interface with the spacer material. The cement raw material can be a cement reactant or an activator.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
76.
METHOD OF VISCOSIFYING WATER-BASED EPOXY RESIN CONSOLIDATION FLUID
Embodiments herein relate to apparatus, compositions, and methods for using a resin consolidation system in a subterranean formation traversed by a wellbore including forming a consolidation treatment fluid using an aqueous solvent, a viscosifying agent, a resin, a curing agent, and a surfactant and introducing the treatment fluid into the formation. In some embodiments, the viscosifying agent includes xanthan, guar, biopolymers, synthetic polymers, viscoelastic surfactants, polyacrylamide, hydroxyethyl cellulose (HEC), carboxymethyl cellulose (CMC), viscoelastic surfactant, or a combination thereof. In some embodiments, the curing agent includes a water-soluble polyamine-based epoxy curing agent. In some embodiments, the resin includes a polymerizable epoxy compound having at least one epoxy group per molecule. In some embodiments, the surfactant includes nonionic and amphoteric surfactant, anionic and cationic surfactant, polymeric surfactant, or a combination thereof. The treatment fluid may further include an oxidative breaker solution.
A method is disclosed that includes preloading a first set of fasteners of multiple fasteners in a first spaced arrangement around a bolt circle, wherein preloading the first set includes a first sequence starting at a first position, and preloading a second set of fasteners of the multiple fasteners in a second spaced arrangement around the bolt circle, wherein preloading the second set includes a second sequence starting at a second position, wherein a first subset includes one or more fasteners of the multiple fasteners are disposed at one or more first intermediate positions between the first and second positions.
Systems and methods of the present disclosure provide systems and methods for receiving one or more sets of parameters related to an operation corresponding to a wellbore. At a first time, the operation is simulated using the one or more sets of parameters and at least one simulator. Pertinent results from the simulation are recorded and stored in a table. The pertinent results include at least one constraint. At a second time, the constraint is retrieved from the table for performance of the operation, and the constraint is used to control the operation.
A method includes receiving field seismic data that represents a subsurface, identifying features in the field seismic data using a machine learning model that was trained using at least one first synthetic seismic data set that includes one or more features and one or more labels of the features, and at least one second synthetic seismic data set, the first and second synthetic seismic data sets both generated based on a geological model. Noise is injected into the second synthetic seismic data based on the geological model. The method also includes generating a model of the subsurface based at least in part on the features that were identified in the field seismic data using the machine learning model.
A technique facilitates perforating operations. According to an embodiment, a perforating gun system utilizes a plurality of modular perforating gun sections which are readily assembled to create a perforating gun with a desired number and orientation of shaped charge holders. In some applications, the modular perforating gun sections may be formed of plastic, e.g. injection moldable plastic, to further reduce costs and provide great flexibility with respect to construction of the desired perforating gun.
Methods and systems are provided for monitoring operational characteristics of a drilling system that includes a bottom hole assembly having a drill collar operably coupled to a drill bit. A device having an elongate beam and at least one pair of sensors is rigidly secured to a part of the bottom hole assembly to measure strain in the part of the bottom hole assembly. The measurement of strain can be used to derive a measurement of at least one operational parameter of the drilling system, such as dog leg severity of a wellbore, torque on bit, and/or weight on bit.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
G01L 5/00 - Apparatus for, or methods of, measuring force, work, mechanical power, or torque, specially adapted for specific purposes
According to various embodiments, techniques for providing a subsurface master record for a subsurface data record are presented. The techniques include: determining at least one subsurface data record for mastering; obtaining a respective subsurface master record that matches the at least one subsurface data record; and merging the at least one subsurface data record with the respective subsurface master record. The techniques may also include updating each subsurface data record of the at least one subsurface data record with an indication of a relationship between the each subsurface data record and the respective subsurface master record.
G06F 7/14 - Merging, i.e. combining at least two sets of record carriers each arranged in the same ordered sequence to produce a single set having the same ordered sequence
A method of operating a thermal system implementing a ground-source heat pump includes receiving design parameters associated with a design of the thermal system and receiving one or more measurement inputs associated with a flow of a thermal fluid through a borefield of a ground heat exchanger. The method further includes, based on the measurement inputs and the design parameters, predicting one or more predicted thermal values of the thermal fluid using a forward model. The method further includes predicting one or more predicted borefield parameters of the borefield based on inverting the forward model. The method further includes monitoring the thermal system based on the predicted borefield parameters.
F24T 10/13 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes
A method for deploying a tool in a well on an electrical cable comprises attaching a cable suspension and recovery device to the cable at a position chosen such that the device is disposed below a wellhead at an upper end of the well when the tool is disposed at a selected depth in the well. The device has a diameter larger than a landing profile disposed in the well, the device having a diameter enabling free movement through the well and flow of fluid around the device in the well. The tool is attached to an end of the cable. The tool is deployed in the well by extending the cable.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
Embodiments presented provide for cable connections that may be used for downhole operations. In embodiments, cable sockets and structural unloading arrangements are used with composite cables to structurally unload data carrying inner core cable components, thereby increasing service life.
H02G 1/14 - Methods or apparatus specially adapted for installing, maintaining, repairing, or dismantling electric cables or lines for joining or terminating cables
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
Amine-based solvents, carbon dioxide capture systems, and methods for improving stability of carbamate during carbon dioxide capture are disclosed herein. The amine-based solvents comprise at least one cyclic amine having a first molecular site that is structurally modified to be protonated and a second molecular site that is structurally modified to hold carbon dioxide as carbamate. The carbon dioxide capture systems comprise at least one gaseous stream comprising carbon dioxide and the amine-based solvent in contact with the at least one gaseous stream. The methods for carbon dioxide capture comprise contacting at least one modified cyclic amine to a gaseous stream comprising carbon dioxide such that the modified at least one cyclic amine chemically reacts with carbon dioxide to form a soluble compound.
B01D 53/14 - Separation of gases or vapoursRecovering vapours of volatile solvents from gasesChemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
A method for deploying a tool in a well on an electrical cable comprises attaching a cable suspension and recovery device to the cable at a position chosen such that the device is disposed below a wellhead at an upper end of the well when the tool is disposed at a selected depth in the well. The device has a diameter larger than a landing profile disposed in the well, the device having a diameter enabling free movement through the well and flow of fluid around the device in the well. The tool is attached to an end of the cable. The tool is deployed in the well by extending the cable.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
88.
SYSTEM AND METHOD FOR OPERATING GROUND-SOURCE HEAT PUMPS
A method of operating a ground-source heat pump (502) includes generating a thermal power based on a thermal communication of the ground-source heat pump (502) with a borefield (508), the thermal power at least partly covering a thermal load of a facility. The method includes receiving a temperature associated with the borefield (508) and controlling the thermal power based on the temperature. The method further includes maintaining the temperature within a temperature ranged based on controlling the thermal power, wherein the ground-source heat pump (502) is configured to cause the temperature to fall outside of the temperature range at a full capacity of the thermal power.
F24T 10/13 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground using tube assemblies suitable for insertion into boreholes in the ground, e.g. geothermal probes
F24D 3/18 - Hot-water central heating systems using heat pumps
A device, includes a hydraulic unit configured to be fluidly connected to a geothermal loop, a sensor configured to measure at least a parameter of a fluid circulating in the geothermal loop and through the hydraulic unit, wherein the parameter comprises at least one of: pressure, flow rate, temperature, density, and viscosity of the fluid circulating in the geothermal loop, and a computing device comprising a processor and a memory, wherein the computing device is configured to receive data from the sensor, calculate, via the processor, a pressure loss based on the data, and determine, based on the pressure loss in view of a predetermined theoretical pressure loss of the geothermal loop, if an integrity of the geothermal loop corresponds to a predetermined criteria to test the integrity of the geothermal loop.
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
F03G 7/04 - Mechanical-power-producing mechanisms, not otherwise provided for or using energy sources not otherwise provided for using pressure differences or thermal differences occurring in nature
Methods and systems are provided that calculate data representing an estimate of formation strength while drilling. The methods and systems employ a drill bit that is instrumented with a first sensor and a second sensor. A processor is configured to i) determine and store first data representing cutting forces acting on a cutting element of the drill bit while drilling based on measurements of the first sensor while drilling, ii) determine and store second data representing depth of cut of the drill bit while drilling based on measurements of the second sensor while drilling, and iii) process the first data and second data to generate and store data representing contact stress against the formation while drilling. This resultant data can be used as an estimate of formation strength. This estimate of formation strength is similar to UCS and can be used in oilfield operations/planning, such as formation characterization while drilling, or drilling efficiency analysis while drilling.
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
E21B 10/42 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
E21B 47/026 - Determining slope or direction of penetrated ground layers
E21B 47/26 - Storing data down-hole, e.g. in a memory or on a record carrier
A method for processing a PCD element includes placing the PCD element in a vessel. A first fluid may be applied to the PCD element when the PCD element is in the vessel. A second fluid may be applied to the PCD element when the PCD element is in the vessel. A first temperature may be applied to the PCD element when the PCD element is in the vessel. A second temperature may be applied to the PCD element when the PCD element is in the vessel.
The disclosure relates to an emission detector for monitoring methane emissions at one or more industrial facilities. The emission detector includes: an enclosure that supports a plurality of sensors, wherein the enclosure is configured to permit atmospheric gas to flow by diffusion into space at or near the plurality of sensors, wherein the plurality of sensors include at least one atmospheric sensor configured to measure atmospheric properties of the atmospheric gas that flows into the space at or near the plurality of sensors as well as at least one gas sensor configured to measure concentration of methane in the atmospheric gas that flows into the space at or near the plurality of sensors.
A method includes receiving baseline data representing an area corresponding to a first time. receiving first measurement data representing a first portion of the area corresponding to a second time subsequent to the first time. training a machine learning model to reduce an influence of a non-repeatability factor based on a combination of the baseline data and the first measurement data. receiving second measurement data representing a second portion of the area corresponding to the second time. the second portion of the area including a feature of interest that was not present at the first time or that has changed between the first and second times. and modifying the second measurement data using the machine learning model to remove the non-repeatability factor in the second measurement data.
A computational framework can include a network interface that receives data from multiple field sites; a processor-based predictor that utilizes at least a portion of the data to generate predictions for production and emissions at each of the multiple field sites; and a processor-based pathway generator that utilizes the predictions to generate an action pathway with different actions for implementation at one or more of the multiple field sites.
A method can include receiving seismic data of a seismic survey of a subsurface region; performing a full waveform inversion using the seismic data and a model of the subsurface region to determine one or more characteristics of the subsurface region, where the model of the subsurface region includes one or more angle-dependent model parameters; and outputting the one or more characteristics of the subsurface region.
An apparatus can have a seal module located at an upper portion thereof. The apparatus can also have a mud line formed through the upper portion of the apparatus and a mud outlet in fluid communication with the mud line. The apparatus can also include a mud pulser adjacent the mud outlet, wherein the mud pulser is configured to be actuated to open, partially close, and close the mud outlet.
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 23/03 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for setting the tools into, or removing the tools from, laterally offset landing nipples or pockets
E21B 23/08 - Introducing or running tools by fluid pressure, e.g. through-the-flow-line tool systems
A method of detecting wear of a downhole tool implemented in a subject wellbore includes receiving offset wellbore data for one or more offset wellbores and, based on the offset wellbore data, determining an expected downhole tool index for the downhole tool at one or more measurement depths including an active measurement depth of the subject wellbore. The method further includes receiving subject wellbore data and, based on the subject wellbore data, determining a subject downhole tool index in real time for the downhole tool at the active measurement depth. The method further includes determining the wear of the downhole tool based on comparing the subject downhole tool index to the expected downhole tool index at the active measurement depth in real time.
E21B 41/00 - Equipment or details not covered by groups
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
Systems and methods for processing vertical seismic profile (VSP) data based on an elastic waveform inversion (EWI). The EWI uses P-wave or S-wave velocity and density information above a total depth of a well and the VSP data to invert parameters including a one dimensional (1D) depth, P-wave or S-wave velocity, density, and attenuation below the total depth. The EWI includes computing a template reflection and searching potential reflections using a cross-correlation between the template reflection and the VSP data. The EWI includes a grid search used to invert the parameters for each subsurface layer below the total depth and a fine-tuning to optimize the inverted parameters based on a downhill simplex method.
Embodiments presented provide for using machine learning-based models in hydrocarbon recovery projects. In embodiments, stimulation efficiency is determined through a machine learning based model to enhance hydrocarbon recovery in wellbore applications. A method may include providing a computer model configured to use artificial intelligence. The method may include feeding the computer model data obtained from one of an optic-acquired vibration dataset and a fiber optic cable dataset, and training the computer model on the optic-acquired vibration dataset and the fiber optic cable dataset. The method may include obtaining surface data and inputting the surface data into the computer model, and predicting stimulation efficiency of a wellbore treatment for the wellbore based upon the surface data.
A method for determining a state variable representing a subsurface formation includes receiving a state variable representing a subsurface formation. The state variable includes a time stamp with a current value and a predicted value associated therewith. The method also includes evaluating a partial differential equation (PDE) based upon the state variable using a numerical simulator. The PDE is evaluated for the current value and/or the predicted value. The method also includes evaluating a matrix based upon the PDE using the numerical simulator. The method also includes determining a gradient based upon the matrix using the numerical simulator. The method also includes training a machine-learning (ML) model to produce a trained ML model. The ML model is trained based upon the gradient. The method also includes updating the state variable using the trained ML model to produce an updated state variable.
