An electric chemical injection (eCI) system may comprise a first injection line, a first on-off valve, and a screen. The screen may comprise a bypass, the screen being positioned between the first injection line and the first on-off valve. A first T-connector may be positioned between the first injection line and the screen. A choke may be configured to allow a given amount of fluid to flow, and the choke may comprise an indexer. A calibration pressure device may be included. A check valve may be provided, and the check valve may comprise a check valve ball and a spring. The check valve may be configured to allow fluid flow from a surface to a well through the first injection line while preventing reverse fluid flow.
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
2.
METHOD FOR USING A CLOSED LAYER MODEL AS TRAINING DATA FOR MACHINE LEARNING
A method for generating a closed layer model of a subsurface includes receiving input data including a 3D seismic volume having a plurality of horizons. The method also includes identifying labeled areas of the plurality of horizons based to produce identified labeled areas for the plurality of horizons. The method further includes determining lateral extents of the identified labeled areas based on the input data, and sorting the plurality of horizons based on the lateral extents to produce a plurality of sorted horizons. The method also includes identifying boundary points of the plurality of horizons based on the lateral extents, and creating truncation maps for the plurality of horizons based on the boundary points of the plurality of sorted horizons. The method also includes generating the closed layer model based on the plurality of horizons and the truncation maps thereof.
Certain aspects of the disclosure provide apparatuses and methods for graphical geological process models that use FM to generate maps for offshore cable routes. A method includes receiving, by a geological process model (GPM), a data input; selecting, an FM algorithm of a plurality of FM algorithms, wherein the FM algorithm is based on a type of the data input; generating, a data output using the FM algorithm, wherein the data output comprises a prediction result of a sedimentation factor; and generating, by the GPM, a graphical layer of an interactive graphical model based on the data output, wherein the graphical layer comprises a graphic associated with the prediction result.
Embodiments presented provide for formation testing in geological stratum that exhibit low permeability. In embodiments, a drill pipe supplied acid and/or proppant is injected into the low permeability stratum through action of a formation tester, thereby altering the permeability of the geological stratum.
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 for analyzing drilling cuttings includes extracting a sample of drilling cuttings from a subterranean formation, the sample including consolidated particles and unconsolidated material. The method includes photographing the sample to produce a photograph, performing an image analysis on the photograph to identify segments of the photograph visualizing the unconsolidated material and excluding visualization of the consolidated particles, and analyzing the segments by performing at least one of a spectral measurement, a texture analysis, a grain size distribution analysis, or a reservoir parameter estimation of the segments. The method enables extraction of geological information from both consolidated and unconsolidated fractions of drilling cuttings samples that would otherwise be discarded in conventional sieving processes, thereby preserving subsurface information including grain size, mineral composition, and other parameters for comprehensive geological characterization of subterranean formations.
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 15/0227 - Investigating particle size or size distribution by optical means using imagingInvestigating particle size or size distribution by optical means using holography
The present disclosure provides a method for predicting a target log frequency distribution within a depth interval. The method includes extracting drilling cuttings from a reference well and capturing a plurality of photographs of the drilling cuttings, wherein each photograph corresponds to a specific depth interval of a plurality of depth intervals. The method includes obtaining a reference target log from the reference well covering the plurality of depth intervals and extracting a plurality of image features from each photograph. The method includes capturing property variability within each depth interval including converting the plurality of image features and the reference target log into normalized frequency distributions. The method includes predicting model property variability by training a prediction model using the normalized frequency distributions of the image features as input data and the normalized frequency distribution of the reference target log as output data.
E21B 44/04 - Automatic control of the tool feed in response to the torque of the drive
E21B 45/00 - Measuring the drilling time or rate of penetration
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
7.
INSTRUMENTED ENGAGEMENT ELEMENT WITH INCREASED WEAR RESISTANCE
An instrument assembly for taking downhole measurements includes an engagement element housing (524) configured to connect to a body of a downhole tool having a diaphragm (536). An engagement element (521) is positioned within the engagement element housing and is rotatable within the engagement element housing about an axis of rotation (560) of the engagement element. The axis of rotation of the engagement element is transverse to a longitudinal axis (562) of the engagement element housing. An engagement sensor (523) is positioned on the diaphragm and configured to take one or more measurements based on the engagement element engaging a formation. The instrument assembly includes electronics including a processor and a power source.
A method includes identifying a cutting element wear library containing a plurality of cutting element items (610). Cutting element information of the cutting element items includes wear information, position information, and context information for cutting elements implemented in wellbore forming operations. A target application data set includes a set of cutting element items corresponding with an application criteria based on the cutting element information for the plurality of cutting element items (630). The set of cutting element items are grouped into a plurality of radial intervals corresponding with a tool radius of a target downhole tool based on the position information (640). The method includes selecting a radial interval based on the wear information of the grouped cutting element items at each radial interval (650), and indicating to position the instrumented engagement element on the target downhole tool within a rotational path and rotationally behind a cutting element in the selected radial interval (660).
A downhole tool (410) for forming a wellbore in a formation includes a rotary engagement component (420) including one or more penetrating elements (424) for forming a plurality of penetrations in the formation defining a rotational sweep (430) of the rotary engagement component, and a cutting structure (412) formed on a body of the downhole tool having one or more cutting elements (423) positioned thereon for degrading the formation. The downhole tool includes an instrumented engagement element (421) positioned on the cutting structure and positioned to engage the formation at an engagement radius that is outside of the rotational sweep of the rotary engagement component, and an engagement sensor connected to electronics for taking one or more measurements associated with the instrumented engagement element engaging the formation.
A system may obtain one or more engagement measurements including at least one engagement measurement of a surface in a wellbore from an engagement sensor, wherein the engagement sensor is housed in an electronics housing positioned within a body of a downhole tool. A system may obtain accelerometer data from an accelerometer that is concurrent with the one or more engagement measurements. A system may correlate data variations in the one or more engagement measurements and in the accelerometer data, wherein the data variations are values outside of a threshold value. A system may identify at least one drilling dysfunction based on correlated accelerometer data and engagement measurements. A system may change at least one wellbore parameter based on the correlated accelerometer data and engagement measurements.
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
E21B 47/10 - Locating fluid leaks, intrusions or movements
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 31/00 - Fishing for or freeing objects in boreholes or wells
An instrument assembly includes a housing positioned within a body of a downhole tool, and electronics positioned within the housing including a processor and a power source. An instrumented engagement element is connected to the body of the downhole tool and positioned to engage a formation. An engagement sensor is connected to the electronics for taking one or more measurements associated with the instrumented engagement element engaging the formation.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
12.
SYSTEMS FOR REMOVING CARBON DIOXIDE FROM A CARBON DIOXIDE‑CONTAINING GAS, AND RELATED METHODS
A system for recovering carbon dioxide from a carbon dioxide-containing gas includes an absorber configured to absorb carbon dioxide from the carbon dioxide-containing gas with a non-aqueous solvent to form a carbon dioxide-lean gas, the non-aqueous solvent comprising a nitrogenous base, regenerator configured to remove the carbon dioxide from the non-aqueous solvent after the non-aqueous solvent is loaded with carbon dioxide, and an acid wash column configured to remove a second portion of the nitrogenous base from the carbon dioxide-lean gas with a buffered acid solution. Related systems and methods of removing carbon dioxide from a carbon dioxide-containing gas are also disclosed.
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 21/26 - Separation of sediment aided by centrifugal force
Embodiments described herein provide perforating guns having one or more perforating charges and an initiator assembly. The initiator assembly includes one or more detonators configured to cause detonation of the one or more perforating charges. In addition, the initiator assembly includes one or more mechanical components configured to be actuated to transition the initiator assembly from a first mechanical configuration to a second mechanical configuration, wherein a detonation circuit of the initiator assembly is open when the initiator assembly is in the first mechanical configuration and the detonation circuit of the initiator assembly is closed when the initiator assembly is in the second mechanical configuration.
xx) from a gas flow into a solvent of a solvent flow to produce a treated gas flow. The system includes a regenerator configured to strip the carbon oxides from the solvent flow to produce a captured carbon oxides flow. The system further includes a wash system configured to wash the treated gas flow using water. The system also includes an appendix stripper system configured to separate a outflow stream into a reclaimed amine stream and a waste stream, wherein the outflow stream comprises the solvent and degraded components of the solvent, and the waste stream has a greater concentration of the degraded components than in the reclaimed amine stream.
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
The present disclosure relates to systems and methods for automatically identifying candidate wells for intervention opportunities in a field. The systems and methods use machine learning models to automate the data analysis to identify the candidate wells. The systems and methods provide insights for the candidate wells and recommendations for the intervention opportunities.
A method for determining a viscosity of undefined petroleum fractions includes obtaining an experimental data set representing a viscosity of a fluid in a well. The method also includes determining a correlation of the viscosity. The method also includes determining a discontinuity in the correlation. The method also includes generating synthetic extrapolation data based upon the discontinuity. The method also includes determining a resulting correlation based upon the synthetic extrapolation data and a training portion of the experimental data set. The method also includes determining the viscosity of undefined petroleum fractions of the fluid in the well based at least in part on the resulting correlation.
17.
METHOD FOR DETECTING BIT ENAGEMENT WITH A GEOLOGICAL FORMATION IN REAL-TIME
A method for detecting bit engagement with a geological formation in real-time. The method includes receiving data from a plurality of sensors disposed at a wellsite. The received data may include hookload data, surface RPM data, surface torque data, block position data, flow rate data, and standpipe pressure data. A plurality of rig activity probabilities may then be determined from the received data. The method further includes desensitizing the received sensor data using a plurality of change point detection means which may also generate a plurality of probabilities indicating if a bit disposed at the wellsite is engaging with the geological formation. The probabilities which indicate that the bit is engaging with the geological formation may be combined with a generated plurality of probabilities which indicate that the bit is resisting engagement to form a composite probability, which in turn may then be used to perform a wellsite action.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 41/00 - Equipment or details not covered by groups
18.
DYNAMICALLY VARIABLE SAMPLING FREQUENCY FOR INSTRUMENTED ENGAGEMENT ELEMENT
A method of operating an instrumented engagement element positioned at an engagement radius on a rotating downhole tool includes taking one or more first measurements with a sensor of the instrumented engagement element at a first sampling frequency based on the engagement radius and based on a first rotational speed of the downhole tool (510). The method includes identifying a change in rotational speed of the rotating downhole tool from the first rotational speed to a second rotational speed (520). The method further includes taking one or more second measurements with the sensor of the instrumented engagement element at a second sampling frequency based on the engagement radius and based on the second rotational speed (530).
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
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
19.
IMPLEMENTING OPERATION MODES FOR INSTRUMENTED ENGAGEMENT ELEMENT THROUGH DOWNLINKS
A method of operating an instrumented engagement element positioned on a downhole tool, the instrumented engagement element configured for engaging a formation within a wellbore, includes operating, in a first operating mode, an instrument assembly positioned within a body of the downhole tool, the instrument assembly including the instrumented engagement element, a sensor of the instrumented engagement element, and a processor (510). The method includes receiving, with the instrument assembly, a downlink encoded via a downhole parameter (520). The method includes operating the instrument assembly in a second operating mode based on decoding the downlink (530).
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
E21B 47/16 - 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 drill string or casing
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
20.
THERMAL BARRIERS FOR INSTRUMENTED ENGAGEMENT ELEMENT
A system for taking downhole measurements includes an instrument assembly positioned within a body of a downhole tool. The instrument assembly includes a housing (314), and electronics (325) positioned within the housing including a processor (325-1) and a power source (325-2). The instrument assembly includes an instrumented engagement element (321) extending at least partially from the downhole tool and configured to engage a formation, and an engagement sensor (323) for taking one or more measurements associated with the instrumented engagement element engaging the formation. The system includes means (332) for preventing the electronics of the instrument assembly from exceeding a temperature threshold of the electronics.
A method of operating an instrumented engagement element positioned on a downhole tool, the instrumented engagement element configured for engaging a formation within a wellbore, includes, operating, in a first operation mode, an instrument assembly positioned within a body of the downhole tool, the instrument assembly including the instrumented engagement element, an engagement sensor of the instrumented engagement element, and a processor (510). The method includes monitoring, with one or more sensors of the instrument assembly, one or more downhole parameters within the wellbore (520), the method includes determining a trigger (530) based on identifying a trigger signature in the one or more downhole parameters. The method includes operating the instrument assembly in a second operation mode in response to the trigger (540).
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 45/00 - Measuring the drilling time or rate of penetration
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
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
22.
INSTRUMENTED ENGAGEMENT ELEMENT AND METHODS OF USE
An instrument assembly for taking downhole measurements includes an electronics housing (314) positioned within a body of a downhole tool, a processor (325-1) positioned within the electronics housing, and a power source (325-2) positioned in the electronics housing. The instrument assembly includes an instrumented engagement element positioned on the downhole tool, wherein the instrumented engagement element extends from the downhole tool and is oriented to engage a wellbore wall of a wellbore. The instrument assembly includes an engagement sensor for taking measurements associated with the instrumented engagement element engaging the wellbore wall.
E21B 10/32 - Drill bits with leading portion, i.e. drill bits with a pilot cutterDrill bits for enlarging the borehole, e.g. reamers with expansible cutting tools
A method can include acquiring sensor data from a facility; quantifying greenhouse gas emissions from equipment components at the facility; determining uncertainty for the greenhouse gas emissions from the equipment components; and issuing a control instruction to the facility to reduce the greenhouse gas emissions or to reduce the uncertainty.
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
E21B 41/00 - Equipment or details not covered by groups
A method for determining and characterizing connection practices for a drill string to prevent transient drilling dysfunctions includes receiving first surface data. The first surface data is related to a plurality of first connections that are made to form one or more first drill strings. The method also includes performing surface comparisons based upon the first surface data. The method also includes identifying connection practices used to make the first connections. The method also includes training a machine-learning (ML) model based upon the surface comparisons and connection practices to produce a trained ML model. The method also includes receiving second surface data. The method also includes selecting one of the connection practices to minimize transient drilling dysfunctions of the second drill string. The selection is made using the trained ML model based upon the second surface data.
Systems and methods for well integrity evaluation are provided. A method for managing well completion includes: obtaining measurement data for a well completion in a geological formation where a wellbore of a well is disposed, pre-processing the measurement data to obtain raw dispersion estimates of frequency slowness content of acoustic energy corresponding to at least one borehole mode, obtaining a dispersion image including dispersion image data using the raw dispersion estimates, based on an accumulation of raw estimated dispersion estimates of frequency-slowness content of borehole acoustic modes, generating a template image using a template dispersion curve corresponding to at least one vicinity of the template dispersion curve, extracting a dispersion quality image of a borehole mode, extracting a dispersion quality metric of the borehole mode, and determining a confidence value for at least one estimated well property for the well based on the dispersion quality, using the template dispersion curve.
A method for classifying lithology facies includes receiving a processed and interpreted borehole image. The method also includes receiving an openhole log. The method also includes pre-processing the borehole image to produce a pre-processed borehole image. The method also includes pre-processing the openhole log to produce a pre-processed openhole log. The method also includes modeling the pre-processed borehole image and the pre-processed openhole log to produce a first modelled output and a second modelled output, respectively. The method also includes concatenating the first modelled output and the second modelled output from first and second heads of the convolutional neuron network to produce a concatenated output. The method also includes passing the concatenated output through a softmax layer. The method also includes classifying lithology facies in the subsurface formation based at least partially upon an output of the softmax layer.
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
G01V 3/38 - Processing data, e.g. for analysis, for interpretation or for correction
22, wherein the fluid maintains a viscosity of at least 70 cp after exposure to temperatures of 200°F to 300°F for at least 90 minutes. The foam fluid demonstrates thermal stability at high temperatures and maintains stable viscosity under high temperature and pressure conditions, making the fluid suitable for hydraulic fracturing applications in high-temperature reservoirs.
C09K 8/60 - Compositions for stimulating production by acting on the underground formation
C09K 8/74 - Eroding chemicals, e.g. acids combined with additives added for specific purposes
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 8/80 - Compositions for reinforcing fractures, e.g. compositions of proppants used to keep the fractures open
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
28.
ROLLER CONE HYBRID BIT WITH PDC GAUGE TRANSITION REGION
A drill bit with fixed blades and roller cones that has a bit cutting profile. The bit cutting profile is made up of the fixed cutting profile and the roller cone cutting profile such that fixed cutting elements are positioned outside of the gauge of the drill bit in a portion of the gauge region and where the roller cone cutting elements are positioned outward from the fixed cutting elements in the innermost, central and transition regions of the drill bit.
E21B 10/14 - Roller bits combined with non-rolling cutters other than of leading-portion type
E21B 10/16 - Roller bits characterised by tooth form or arrangement
E21B 10/20 - Roller bits characterised by detachable or adjustable parts, e.g. legs or axles
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/627 - Drill bits characterised by parts, e.g. cutting elements, which are detachable or adjustable with plural detachable cutting elements
E21B 10/55 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of the rotary drag type, e.g. fork-type bits with preformed cutting elements
A guide arm assembly for incorporation into a derrick at an oilfield rig. The assembly includes a vertical support and an articulating arm which are conscious of the limited derrick floorspace available. The vertical support is secured at a frame of a V-door which defines a V-doorway. The V-doorway defines a point of entry or exit to the derrick floorspace and is also outside of the derrick floorspace. An articulating arm is coupled to the vertical support and is configured for physically manipulated guidance of an implement from one location at the derrick floorspace to another location of the derrick floorspace that includes a well center that is positioned over a wellsite below the rig.
E21B 19/14 - Racks, ramps, troughs or bins, for holding the lengths of rod singly or connectedHandling between storage place and borehole
E21B 19/24 - Guiding or centralising devices for drilling rods or pipes
E21B 15/00 - Supports for the drilling machine, e.g. derricks or masts
E21B 19/087 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods by means of a swinging arm
30.
TECHNIQUES FOR GENERATING AND/OR TRAINING A MODEL FOR PREDICTING PARAMETERS ASSOCIATED WITH WELL OPERATIONS
Systems and methods configured to generate and/or train a model using downhole measurements for one or more well operations. After the model is generated and/or trained, the model can thereafter be used to calculate or estimate one or more downhole parameters for one or more subsequent well operations based on surface data associated with the subsequent well operations.
E21B 47/10 - Locating fluid leaks, intrusions or movements
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 cutting element includes a body defining an upper surface. The upper surface includes a cutting tip, wherein a backrake angle of the body varies along the upper surface from the cutting tip toward a longitudinal axis of the body. The upper surface also includes a back tip positioned opposite the cutting tip, wherein the cutting tip and the back tip are each positioned above a center point of the upper surface positioned at the longitudinal axis of the body. The upper surface further includes a first lateral side between the cutting tip and the back tip, the first lateral side being positioned below the center point, wherein a flange angle of the body varies along the upper surface from the cutting tip toward the longitudinal axis.
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/43 - Rotary drag type drill bits with teeth, blades or like cutting elements, e.g. fork-type bits, fish tail bits characterised by the arrangement of teeth or other cutting elements
32.
AI-DRIVEN FACILITY SENSOR PLANNING AND METHANE LEAK DETECTION
A method for detecting a gas leak includes selecting locations for a plurality of simulated point sources of the gas leak at a site. The method also includes generating a plurality of physical dispersion models based upon the simulated point sources, a selected number of sensors that are configured to detect the gas leak, and selected locations of the sensors. The method also includes determining simulated measurements from the sensors at the selected locations using the plurality of physical dispersion models. The method also includes training one or more models based upon the simulated measurements. The method also includes receiving actual measurements from the selected number of the sensors at the selected locations. The method also includes predicting a location and/or a rate of the gas leak using the one or more trained models based upon the actual measurements.
G01M 3/02 - Investigating fluid tightness of structures by using fluid or vacuum
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 logging system for a subsurface operation includes: a probe positioned within a wellbore extending through a target formation, the probe generating pressure pulses that propagate within a target formation proximate to the wellbore; and a wireline extending along at least a portion of the wellbore. The wireline detects the pressure pulses and generates an electrical signal indicative of an effective flowing thickness of the target formation.
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 method for evaluating a mining site as a potential candidate for application of an emerging mining technology includes acquiring at least one report that provides information about the mining site and generating evaluation queries and criteria related to an application of the emerging mining technology to the mining site. An artificial intelligence (AI) based engine is used to extract query relevant information from the at least one acquired report; classify the extracted query relevant information using the generated criteria; and generate an applicability score that assesses the viability of utilizing the emerging mining technology to mine the mining site.
A method may include accessing drilling data associated with borehole depth; interpolating the drilling data for a drilling behavior with respect to drilling control parameters for a borehole depth range; performing isotonic regression on the drilling behavior to generate a multidimensional control surface for the borehole depth range; and outputting the multidimensional control surface.
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
36.
CONTINUOUS ROTATION COILED TUBING ORIENTING TOOL WITH PASSIVE HYDRAULIC CONTROL
An orienting tool includes a first collar configured to rotate with respect to a second collar. A hydraulic pump is deployed in the first collar. A drive shaft of the hydraulic pump is rotationally coupled to the second collar. The hydraulic pump is configured to provide pressurized hydraulic fluid to a metering valve in the first collar that is configured to restrict flow of the pressurized hydraulic fluid and thereby resist rotation of the drive shaft and the second collar relative to the first collar via back pressure to the hydraulic pump.
An orienting tool includes a first collar configured to rotate with respect to a second collar. A cylinder having self-reversing threads on an outer surface thereof is deployed in the first collar and rotationally coupled with the second collar. A piston assembly includes a threaded piston head configured to travel in first and second opposing axial directions along the self-reversing threads. Movement of the piston head along the cylinder rotates the cylinder and the rotationally coupled second collar in a single rotational direction. A hydraulic pump is deployed in the first collar and is configured to provide pressurized hydraulic fluid to the piston assembly to move the piston head along the cylinder.
A coiled tubing orienting tool includes a first collar configured to rotate with respect to a second collar. A hydraulic pump and a hydraulic motor are deployed in the first collar. The hydraulic pump is configured to provide pressurized hydraulic fluid to the hydraulic motor to drive the hydraulic motor, which is configured to provide rotary torque to the second collar and thereby continuously rotate the second collar with respect to the first collar.
Systems and methods presented herein generally relate to introducing degradable fibers into a clean fluid having no proppants contained therein to produce a fiber-containing fluid, and injecting the fiber-containing fluid into a wellbore extending through a subterranean formation during a PAD stage of a hydraulic fracturing operation. In general, the systems and methods presented herein block fluid leak-off flow through walls of fractures created during hydraulic fracturing operations. Advantages include the ability to definitively minimize fluid damage to the reservoir because less fluid is used and there is less water consumption.
A method for executing multiple applications related to a drilling operation. The method includes aggregating data related to a wellsite, the aggregated data being received from a plurality of sources including equipment disposed within the wellsite and outside systems communicated to the wellsite. The aggregated data is stored within a shared domain service layer of a database, and may be harmonized using a virtual channel. A recommendation or predictive insight based on the stored data may be generated in addition to a command being autonomously sent to the equipment disposed at the wellsite. A wellsite action may then be performed that is based on the stored data. The steps of aggregating the data, storing the aggregated data, generating a recommendation, autonomously sending a command, generating a predictive insight, and performing the wellsite action may be done on the same equipment or edge device disposed at the wellsite.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
A method for monitoring and autonomously addressing anomalies related to a site. The method includes receiving data from a plurality of sources or equipment disposed within a wellsite. An anomaly may be identified within the received data by analyzing performance metrics to determine a high latency and load related to the equipment within the wellsite, analyzing firewall logs and IDS alerts to confirm if there has been suspicious network activity related to the wellsite, identifying repeated connection errors and latency spikes from the network connectivity data or identifying a rapid increase in data volume within the database data related to the wellsite equipment. An insight may then be generated based on the identified anomaly and then a command based on the generated insight is transmitted to the wellsite equipment. A wellsite action based on the transmitted command can then be performed to resolve the anomaly.
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
43.
DIGITAL FLOWMETER FOR WELLBORES IMPLEMENTING ELECTRICAL SUBMERSIBLE PUMPS
In some embodiments, a method of determining flowrate of a production fluid of a downhole system implementing an electrical submersible pump (ESP) includes receiving pressure data of the ESP including input pressure data and output pressure data, and detecting an event of the downhole system associated with a change to one or more downhole conditions based on identifying a change in a pressure differential between the input pressure data and the output pressure data. The method includes classifying the event based on a change in the input pressure data or a change in the output pressure data. The method further includes updating a hydraulic model of the downhole system based on the classification of the event and based on the pressure differential, and determining a flowrate of the production fluid downhole system with the updated hydraulic model.
A cutting element may include a polycrystalline diamond (PCD) table. A cutting element may include a body including: a carbide substrate bonded directly to the PCD table, the carbide substrate including a first plurality of carbide particles and a first matrix phase interspersed between the carbide particles of the first plurality of carbide particles, and a base layer bonded directly to the carbide substrate, the base layer including a second plurality of carbide particles and a second matrix phase interspersed between the carbide particles of the second plurality of carbide particles, wherein the second plurality of carbide particles has a second grain size greater than a first grain size of the first plurality of carbide particles.
A valve, comprising: a valve body, a valve member, and a valve seat. The valve body includes a bore configured to receive fluid flow and proppant flow. The valve member is movable between a closed position and an open position. The valve seat is disposed between the valve member and the valve body. The valve seat includes a first seat body and a sealing element. The first seat body is movable relative to the valve body between a first position and a second position, wherein in the second position, the first seat body sealingly engages with the valve member. The sealing element permits fluid flow from the bore to apply a pressure on a surface of the first seat body to move the first seat body from the first position to the second position, and wherein the sealing element prevents proppant flow to the surface of the first seat body.
F16K 3/20 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor with special arrangements for separating the sealing faces or for pressing them together by movement of the seats
F16K 3/02 - Gate valves or sliding valves, i.e. cut-off apparatus with closing members having a sliding movement along the seat for opening and closing with flat sealing facesPackings therefor
F16K 27/04 - Construction of housingsUse of materials therefor of sliding valves
A method may include controlling a computational simulator to perform an inner loop that solves mass balance and energy balance of a rate-based separation process using thermodynamic and physical properties to generate an inner loop result; controlling the computational simulator to perform an outer loop using the inner loop result to generate an outer loop result that includes updated thermodynamic and physical properties; and controlling the computational simulator to terminate performance of the inner loop and the outer loop responsive to iterative convergence of the outer loop result.
A method can include accessing data for a number of reservoir sites, where the data include at least property data for reservoir properties; performing a determination, using the property data for the reservoir sites, as to whether the reservoir properties for the reservoir sites are independent; responsive to the determination, implementing a Sobol' indices technique or a Kucherenko indices technique to generate global sensitivity analysis results that include property indices for the reservoir properties; generating confidence intervals for the property indices; and generating a graphical user interface for rendering the property indices with the confidence intervals for a number of the reservoir properties.
48.
BOTTOM INTAKE ELECTRIC SUBMERSIBLE PUMP PROTECTOR GAS REJECTION DEVICE
A gas rejection device for an electric submersible pump (ESP) protector has a first fluid chamber having a pressure equalization port proximate a top thereof in fluid communication with an exterior of the ESP. A second fluid chamber is disposed above the first fluid chamber. The first and second fluid chambers are arranged to be disposed between a pump of an ESP system and the ESP protector. The second fluid chamber is arranged to be placed in fluid communication with an oil reservoir in the protector. The device comprises a fluid passage between an upper end of the at least a second fluid chamber and the exterior of the ESP, wherein gas accumulated in the upper end vents to the exterior of the ESP.
A fluid composition includes a sulfide scavenger formulation to reduce a concentration of one or more sulfide species in a production stream and a solids control additive to reduce solid formation in the production steam as a result of reaction of the sulfide scavenger formulation and the one or more sulfide species.
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
50.
CUTTING INSERTS WITH A MODIFIED NON-PLANAR CUTTING VOLUME FOR USE IN A DOWNHOLE BIT
A cutting insert may include a substrate body and a cutting volume. The cutting volume is a non-planar cutting volume with a plurality of intersecting curvatures that extend from a lateral surface of the substrate body to form a cutting ridge and an apex of the cutting insert. The substrate body and the cutting volume being within a defined form factor of the cutting insert.
A method can include receiving input for a number of reservoir parameters; generating for the number of reservoir parameters a number of reservoir characterization profiles with respect to time using a trained machine learning model; and performing one or more field operations using field equipment based at least in part on one of the number of reservoir characterization profiles.
A system for cooling drilling fluid on a drilling rig includes a heat exchanger and a solid-state chiller including at least one of a magnetocaloric chiller, an electrocaloric chiller, and an elastocaloric chiller. A first pump is configured to circulate drilling fluid through the heat exchanger and a second pump is configured to circulate a coolant through the solid-state chiller and the heat exchanger. The solid-state chiller is configured to cool the coolant circulating therethrough and thereby cool drilling fluid circulating through the heat exchanger.
Fracturing fluid delivery systems having conduits with sleeves are provided. In one example, a method of installing a sleeve includes inserting a rigid sleeve (58) into a bore (68) of a flexible fracturing fluid conduit (48) that includes a flexible body portion (52) connected to a rigid end portion (56). The method also includes positioning the rigid sleeve within the bore such that the rigid sleeve is located at least partially within the flexible body portion and radially expanding the positioned rigid sleeve to induce plastic deformation of the rigid sleeve and cause an outer surface of the rigid sleeve to form a circumferential seal with an inner surface of the flexible body portion. Additional systems, devices, and methods are disclosed.
A method includes receiving, via a processing system, unstructured data associated with one or more operations performed in a production system, extracting, via the processing system, information from the unstructured data based on one or more domain specific prompts associated with the production system. The method also includes integrating, via the processing system, the information with structured data to generate updated structured data, receiving, via the processing system, a request associated with the one or more operations, and generating, via the processing system, a response based on the updated structured data, wherein the response includes a visualization representative of the response.
A bit may include a body. A bit may include a plurality of blades extending from the body. A bit may include a bit connection extending uphole from the body. A bit may include a skirt extending from the body, the skirt extending at least partially over the bit connection to form an annular connection space between the skirt and the bit connection.
A toe valve system positioned along a tubing string. The toe valve system a piston sleeve slidably disposed in an outer housing which has ports therethrough. The toe valve system comprises a shifting sleeve shiftable between positions with respect to the ports. A piston sleeve initially held in a position closing off the at least one port to prevent flow between the interior and exterior of the tubing string. A compensator sleeve mounted within the outer housing, wherein the compensator sleeve is free floating and can accommodate changes in tubing pressure. A piston chamber filled with a liquid which is located between the piston sleeve, the compensator sleeve and the outer housing. The liquid in the piston chamber is retained by a rupture disk that can release the liquid when sufficient pressure is applied within the toe valve system causing the piston sleeve to move and opening the ports.
E21B 34/14 - Valve arrangements for boreholes or wells in wells operated by movement of tools, e.g. sleeve valves operated by pistons or wire line tools
E21B 34/06 - Valve arrangements for boreholes or wells in wells
A cutting element may include a table at a first longitudinal end in a longitudinal direction of a longitudinal axis, the table having a table outer diameter transverse to the longitudinal direction and the table including an ultrahard material. A cutting element may include a core having a core outer diameter that is less than the table outer diameter, the core being coupled to and configured to receive heat from the table. A cutting element may include an annular sleeve radially outside of the core with a sleeve outer diameter no less than the table outer diameter.
E21B 10/573 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts characterised by support details, e.g. the substrate construction or the interface between the substrate and the cutting element
B22F 7/06 - Manufacture of composite layers, workpieces, or articles, comprising metallic powder, by sintering the powder, with or without compacting of composite workpieces or articles from parts, e.g. to form tipped tools
A method for repairing, rejuvenating or reviving at least one aging, or degraded, or underperforming electrolyzer cell, including an oxygen electrode and a hydrogen electrode in to improve, or to enhance electrolysis efficiency and/or to extend the service lifetime of the electrolyzer cell. The method includes providing one or more activation solutions to the electrolyzer cell. The method also includes providing one or more deposition solutions including one or more metal ions to deposit the one or more metals onto at least one of the oxygen electrode and hydrogen electrode after providing the one or more activation solutions. Further, the method includes forming an oxygen evolution reaction (OER) electrocatalyst onto the oxygen electrode using an OER precursor solution, a hydrogen evolution reaction (HER) electrocatalyst onto the hydrogen electrode using a HER precursor solution, or both, after providing the one or more deposition solutions.
C25B 11/053 - Electrodes comprising one or more electrocatalytic coatings on a substrate characterised by multilayer electrocatalytic coatings
C25B 11/075 - Electrodes formed of electrocatalysts on a substrate or carrier characterised by the electrocatalysts material consisting of a single catalytic element or catalytic compound
A system includes a tool string, a kinematic assembly, and a pulley assembly. The kinematic assembly includes a first link and a second link. A first end portion of the first link is rotably coupled to the tool string and a first end portion of the second link is rotably coupled to the tool string. The pulley assembly includes a first pulley coupled to the tool string, and a first cable at least partially reeved about the first pulley. A first end of the first cable is coupled to the kinematic assembly, and a second end of the first cable is coupled to an actuation assembly. The kinematic assembly at least partially retracts into the tool string in response to the actuation assembly pulling the first cable.
E21B 23/00 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells
E21B 41/00 - Equipment or details not covered by groups
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
60.
METHOD FOR PREDICTING OPERATIONS AT A WATER TREATMENT PLANT
A method for predicting a process at a water treatment plant. The method includes receiving coagulation data from the water treatment plant and displaying the received data via a graphical interface, the display including a historical record of the received data. A prediction of the performance of the equipment within the water treatment plant may then be generated, the prediction of the performance including a predicted turbidity or UV transmittance of water after passing through the equipment. The prediction of the performance is based on the data received from the water treatment plant and a plurality of inputs received from the user via the graphical interface. The generated prediction of performance is displayed via the graphical interface, thereby allowing the user to perform an action including selectively activating the equipment, selectively adjusting equipment settings, and selectively adjusting conditions within the water treatment plant that are upstream of the equipment.
C02F 1/00 - Treatment of water, waste water, or sewage
C02F 1/32 - Treatment of water, waste water, or sewage by irradiation with ultraviolet light
C02F 1/44 - Treatment of water, waste water, or sewage by dialysis, osmosis or reverse osmosis
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
61.
SYSTEMS AND METHODS FOR EM-ASSISTED IN-SITU BIOMINING
Systems and methods for electromagnetic (EM)-assisted in-situ biomining are provided. A method for in-situ mining in a rock formation in an area of interest includes: receiving a first micro-organism from a micro-organism source at a first well extending downward from a ground surface in the area of interest, injecting the first micro-organism into a permeable layer of the rock formation via the first well to dissolve a target material to form a solution containing the first micro-organism and the target material, applying an electric field to the first micro-organism by the first well operating as a first electrode and a second well operating as a second electrode, such that the electric field stimulates activity of the first micro-organism, receiving the solution via the second well, and pumping the solution, via the second well, to a processing plant to separate the target material from the first micro-organism.
A method can include receiving a digital well plan for a well at a field site; predicting power demand for execution of an action specified by the digital well plan using a model; and, based at least in part on the predicted power demand, controlling equipment at the field site to perform the action while controlling a power system at the field site to deliver power to the equipment.
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 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 41/00 - Equipment or details not covered by groups
A wellbore fluid includes an aqueous base fluid including water, and at least one salt. The wellbore fluid further includes a corrosion inhibitor composition including at least one of morpholine or hydroxyethyl morpholine, and ascorbic acid. The corrosion inhibitor composition includes at least about 0.80 part by weight of the at least one of morpholine or hydroxyethyl morpholine per every about 1.0 part by weight of the ascorbic acid. Related wellbore fluids, corrosion inhibitor compositions, and methods are also disclosed.
An electric submersible progressive cavity pump (ESPCP) system may include a vortex gas separator assembly (VGSA), comprising a head comprising holes for inserting pin for installation, grooves disposed at both ends for the pin installation, a stator having an internal bore, and a rotor disposed in the internal bore of the stator. The ESPCP system may comprise a flexible shaft unit (FSU) between the VGSA and the ESPCP.
F04D 29/044 - Arrangements for joining or assembling shafts
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
B01D 45/14 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by centrifugal forces generated by rotating vanes, discs, drums or brushes
A system includes a connector body, and a chain slider having a U-shaped structure that is removably installed on the connector body. The chain slider may include an outer groove forming a translation path, and the outer groove may be configured to receive a chain that slides along the translation path.
B63B 21/20 - Adaptations of chains, ropes, hawsers, or the like, or of parts thereof
B63B 21/50 - Anchoring arrangements for special vessels, e.g. for floating drilling platforms or dredgers
B63B 73/20 - Building or assembling prefabricated vessel modules or parts other than hull blocks, e.g. engine rooms, rudders, propellers, superstructures, berths, holds or tanks
A system includes: a connector body, a chain wheel configured to receive a chain, an axle extending through the chain wheel, a first rotation plate disposed on the axle on a first side of the chain wheel, a second rotation plate disposed on the axle on a second side of the chain wheel, and first and second maintain plates affixed to the axle. The first and second rotation plates allow rotation of the chain wheel, and the first and second maintain plates are configured to maintain the first and second rotation plates, respectively, on the axle during an operation. The chain wheel is removably installed on the connector body via the first and second rotation plates.
B63B 21/50 - Anchoring arrangements for special vessels, e.g. for floating drilling platforms or dredgers
B63B 73/20 - Building or assembling prefabricated vessel modules or parts other than hull blocks, e.g. engine rooms, rudders, propellers, superstructures, berths, holds or tanks
A mesoporous carbon sorbent for removal of carbon dioxide from a gaseous material includes a BJH average pore width greater than about 3 nm, and a selectivity of carbon dioxide to nitrogen greater than about 20.00 at about 30°C, a partial pressure of carbon dioxide of about 114 mmHg, and a partial pressure of nitrogen of about 646 mmHg. Related mesoporous carbon sorbents, and methods of forming the carbon sorbents are also disclosure.
A system includes a gas leak instrument configured to monitor for gas leaks from an emission source, wherein the gas leak instrument includes a gas sensor, a wind sensor, and a controller coupled to the gas sensor and the least one wind sensor. The controller has a processor, a memory, and instructions stored on the memory and executable by the processor to cause operations including determining a baseline gas concentration in an environment based on first gas measurements from the gas sensor and first wind measurements from the wind sensor and determining an emission gas rate based on the baseline gas concentration, second gas measurements from the gas sensor second wind measurements from the wind sensor, and the Gaussian plume model.
A system includes a tool string and a caliper assembly. The caliper assembly includes one or more first calipers rotably coupled to the tool string. The one or more first calipers are circumferentially arrayed about a longitudinal central axis of the tool string. The caliper assembly also includes one or more second calipers rotably coupled to the tool string. The one or more second calipers are circumferentially arrayed about the longitudinal central axis. The caliper assembly also includes a drive element disposed within the tool string and slidably coupled to the tool string. The one or more first calipers extend from the tool string in response to the drive element moving to a first position. The one or more second calipers extend from the tool string in response to the drive element moving to a second position.
A system includes a connector body having a bore therethrough, a chain locker disposed at an end of the connector body, and one or more components removably attached to the connector body that guide a chain that moves in tension through the system. The chain locker is integrated with the connector body. Further, the chain locker is fully mechanical and is able to move between a use position, a lock position, and an unlock position with respect to the chain.
A system includes a controller having one or more processors. The system also includes a memory, and instructions stored on the memory, and executable by the one or more processors to output a control signal that causes an actuation of a valve to move a test distance via an electromechanical actuator; receive electrical property data corresponding to the actuation over the test distance by the electromechanical actuator; evaluate a condition of the valve based on the electrical property data; and generate an output based on the condition of the valve.
A method for planning a well action within a field. The method includes providing a plurality of inputs related to the field and then submitting a query related to the plurality of inputs via a graphical interface. A response is then generated to the submitted query and displayed in real-time within the graphical interface. Data analytics may then be performed on the displayed response within the graphical interface and a report can then be generated that is based on the displayed response. An uncertainty and optimization workflow can be provided by submitting a query that includes a range of values corresponding to at least one of the inputs and then generating an ensemble of cases, wherein each case is based on the range of values corresponding to the at least one input. The planned well action may then be performed based on the displayed response.
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 system is provided that includes an imaging system used to obtain images of one or more solids extracted from a reservoir during a projectile motion of the one or more solids, a processing circuitry, and a memory, accessible by the processing circuitry, the memory storing instructions that, when executed by the processing circuitry cause the processing circuitry to perform operations. The operations include controlling the imaging system to obtain the images of the one or more solids during the projectile motion and obtaining one or more physical properties of the one or more solids based on the images of the one or more solids during the projectile motion.
G01N 23/04 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material and forming images of the material
G01N 23/12 - Investigating or analysing materials by the use of wave or particle radiation, e.g. X-rays or neutrons, not covered by groups , or by transmitting the radiation through the material and measuring the absorption the material being a flowing fluid or a flowing granular solid
E21B 47/002 - Survey of boreholes or wells by visual inspection
A method of designing an artificial lift system for producing fluid from a wellbore includes receiving wellbore data indicating configuration specifications and production specifications for the wellbore and identifying a plurality of candidate electrical submersible pump (ESP) designs for implementing in the wellbore based on the wellbore data. The method further includes determining a design score for each of the plurality of candidate ESP designs, the candidate ESP designs each indicating a collection of downhole components defining an ESP system. The design score is based on inventory data for an inventory of available downhole components and historical wellbore data, the historical wellbore data indicating historical conditions for the wellbore and historical production performance for the wellbore. The method further includes selecting an ESP design from the plurality of candidate ESP designs based on an associated design score best fulfilling one or more criteria.
G05B 13/00 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion
A system may obtain azimuth and inclination measurements from a downhole tool in a downhole environment. A system may obtain a downhole ROP and downhole DLS from a downhole control unit. A system may determine a corrected DLS demand based at least partially on a ratio of downhole ROP and surface ROP. A system may transmit a DLS demand setting to the downhole tool based at least partially on the corrected DLS demand and the downhole ROP. A system may drill at least a portion of a borehole with the downhole tool based at least partially on the corrected DLS demand.
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
Certain embodiments of the present disclosure are directed to techniques for creating a filler material within a slickwater slurry. The filler material is generated by adding a cationic additive to the slickwater slurry. The cationic additive can be introduced to the slurry either before, after, or simultaneously with the proppant or friction reducer. Upon addition and mixing with the friction reducer, the cationic additive reacts due to electrostatic attraction, forming gel-like substances or agglomerates. This process, which may be termed complex coacervation, agglomeration, or aggregation, may entrap proppant particles during formation, with proppant particles possibly being trapped within these agglomerates or aggregates. The operation then proceeds as a slickwater treatment. After the proppant is delivered into the fracture and subsequently transported and settled, the agglomerates act as fillers within the proppant pack, thereby reducing its bulk density.
A system may include processing circuitry and memory storing instructions, where the instructions, when executed by the processing circuitry, cause the processing circuitry to receive a set of predicted measurements associated with a property of a well, receive an indication of a subset of the set of predicted measurements, receive a parameter for adjusting the subset, and retrieve a model corresponding to the parameter from a library of correction models. The processing circuitry may also generate an adjusted set of predicted measurements by inputting the subset into the model and instruct a user interface to display the set of predicted measurements and the adjusted set of predicted measurements.
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
G06F 3/048 - Interaction techniques based on graphical user interfaces [GUI]
G06F 17/18 - Complex mathematical operations for evaluating statistical data
A geological software assistant may receive, from a user, an input with a user request regarding geological software. A geological software assistant may identify whether the user request has sufficient details and is compatible with the geological software. A geological software assistant may, when the user request has insufficient details, prepare and provide to the user a follow-up question to clarify the user request. A geological software assistant may, based on the follow-up question, receive additional input including an updated user request. A geological software assistant may, when the updated user request has sufficient details and is compatible with the geological software, generate and input a program query to the geological software, the program query based on the updated user request. A geological software assistant may provide the user an output from the geological software based on the program query, the output responsive to the updated user request.
A system includes processing circuitry and memory storing instructions, where the instructions, when executed by the processing circuitry, cause the processing circuitry to identify one or more tools to generate one or more workflows for analyzing one or more datasets associated with one or more well operations, generate a tool library based on the tools, and receive user input indicative of a property and a set of well measurements. The processing circuitry may also determine a plurality of workflows based on the property, the set of well measurements, and the tool library and generate a ranked list comprising the plurality of workflows based on one or more attributes. The processing circuitry may determine a predicted set of measurements for each workflow of the ranked list and instruct a user interface to display the ranked list and the predicted set of measurements for each workflow of the ranked list of workflows.
A system may include processing circuitry and memory storing instructions, where the instructions, when executed by the processing circuitry, cause the processing circuitry to receive a first set of measurements associated with a first set of wells and generate a first well model representative of a property associated with the first set of wells. The processing circuitry may generate a well property model representative of an expected property relative to a measurement associated with a well, receive a second set of measurements associated with a second set of wells, and generate a second well model representative of a first set of predicted measurements. The processing circuitry may generate an adjusted second well model based on the well property model and the second well model, determine a second set of predicted measurements, and instruct a display to display the first set of predicted measurements and the second set of predicted measurements.
A production digital twin system may generate a model of a wellbore. A production digital twin system may use historical data, calibrating the model. A production digital twin system may receive an updated total production profile from one or more sensors located at a surface of the wellbore. A production digital twin system may update the model with the updated total production profile. A production digital twin system may generate, using the model, a virtual zonal production profile for each of the plurality of lateral production zones, the virtual zonal production profile based on a total production profile.
A method for performing directional drilling includes receiving a steering command to perform a directional drilling action with a downhole tool in a subsurface. The method also includes receiving first input data based upon and/or in response to the steering command. The method also includes modifying the steering command in response to the first input data to produce a first modified steering command to perform a first modified directional drilling action with the downhole tool. The method also includes receiving measured data related to the downhole tool while the first modified directional drilling action is being performed. The method also includes determining one or more outputs based upon the measured data. The one or more outputs are determined by a large language model (LLM) and/or generative artificial intelligence (Gen AI) model.
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 47/024 - Determining slope or direction of devices in the borehole
A method may include drilling a portion of a borehole with a bottomhole assembly (BHA) including the downhole tool in an automated drilling routine. A method may include receiving, at a control unit of the BHA, a disengagement downlink communication having a disengagement magnitude and disengagement duration. A method may include, based at least partially on the disengagement downlink communication, disengaging the automated drilling routine.
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
A method may include drilling a portion of the borehole with a bottomhole assembly (BHA) including a downhole tool. A method may include receiving, at the downhole tool, a zero pulse. A method may include receiving, at the downhole tool, a stand pulse. A method may include determining an added stand length based at least partially on the stand pulse. A method may include adding the added stand length to a total string length.
Systems and methods relate to managing and/or planning production operations, wells, facilities, plants, or other hydrocarbon processing operations with a smart agent. The smart agent can receive a request for information and generate a prompt based on the request for information. The smart agent transmits the prompt to a sub-agent and receives a response from the sub-agent based on the prompt.
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 47/024 - Determining slope or direction of devices in the borehole
A method for optimizing autonomous chemical injections for equipment at a field site. The method includes receiving data from the equipment disposed at the field site and then identifying a real-time value of the received data. The method includes automatically generating an insight in response to the identified real-time value, wherein the insight includes an actionable task related to manual operation of the equipment, an advisory of equipment that is at-risk, or a recommendation to optimize chemical injection within the equipment. The recommendation to optimize chemical injection may include calculating a risk index based on the received data and determining an optimal injection rate and an optimal chemical concentration based the calculated risk index. The method may also include automatically injecting chemicals within the equipment based on the generated insight. The method further includes performing a field site action in response to the generated insight.
A method for determining a performance of a well with an electrical submersible pump (ESP) therein includes receiving input data related to the well. The method also includes generating an ESP curve based upon the input data. The method also includes generating a nodal analysis plot based upon the input data. The method also includes determining a mechanical status of the well based upon the input data. The method also includes determining the performance of the well based upon the ESP curve, the nodal analysis plot, and the mechanical status of the well.
G06F 15/04 - Digital computers in generalData processing equipment in general programmed simultaneously with the introduction of data to be processed, e.g. on the same record carrier
G01F 1/34 - Measuring the volume flow or mass flow of fluid or fluent solid material wherein the fluid passes through a meter in a continuous flow by using mechanical effects by measuring pressure or differential pressure
F04D 13/08 - Units comprising pumps and their driving means the pump being electrically driven for submerged use
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
A method for detecting human-equipment interaction. The method includes receiving at least one image from at least one optical device disposed within a defined work space. At least one human or piece of equipment may be detected at a first position within the work space. A movement of the human and/or the equipment may then be tracked within the work space. A description of the tracked movement of the human and/or equipment may then be generated. An assessment based on the generated description may then be generated, the assessment having an estimated determination whether the human and/or equipment adhered to a set of predetermined instructions and/or safety protocols, wherein the assessment comprises a generated recommendation for additional data. The method may also include performing an action such as a wellsite action or other facility related action in response to the generated assessment.
89.
GEOPOLYMER SLURRIES AND GEOPOLYMER COMPOSITIONS INCLUDING FLUID LOSS CONTROL MATERIALS, AND RELATED METHODS
A geopolymer precursor includes an alkaline reactive solid material containing aluminum, silicon, and oxygen, and a fluid loss control material having an ionic stability property that has a first value in water and a second value in a 3M solution of NaOH, wherein a ratio of the second value to the first value is in a range of 0.5 to 2.0. The fluid loss control material may be, or may include a crosslinked polymer, which may include a reaction product of one or more of acrylamide, 2-acrylamido-2-methyl propane sulfonic acid, N,N‑dimethylacrylamide, N,N‑diethylacrylamide, vinyl acetate, or another monomer, and a crosslinker including one or more of methylene bisacrylamide, triallyl amine, pentaerythritol allyl ether, triallyl-triazine-trione, or another material. The geopolymer precursor may include an activator, an alkaline solution having pH of at least about 9, or both.
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
C09K 8/487 - Fluid loss control additivesAdditives for reducing or preventing circulation loss
90.
GENERATIVE ARTIFICIAL INTELLIGENCE PANEL OF EXPERTS FRAMEWORK
A method implements a generative artificial intelligence panel of experts. The method involves receiving an application query from an application. The method involves classifying the application query to a set of domains identified in a classification response. The method involves generating a set of domain queries for a set of foundational models selected for the set of domains using benchmark data. The method involves receiving a set of model responses corresponding to a set of model prompts corresponding to the set of domain queries. The method involves enriching a set of enrichment queries to generate a set of enriched responses, in which the set of enrichment queries include the set of model responses and the application query. The method involves synthesizing the set of enriched responses to generate a synthesis response. The method involves transmitting an application response corresponding to the application query and generated from the synthesis response.
A method implements an integrated generative artificial intelligence platform. The method involves routing a query from an application to an orchestration agent corresponding to the application. The method involves executing a set of tasks with the orchestration agent based on the query using an orchestration layer as a single point of access to a private data store, a public data store, a private foundational model, and a public foundational model. The method involves executing a retrieval program to access the private data store and/or the public data store for a retrieval task using the orchestration layer to generate retrieval data. The method involves executing an analysis prompt to process the retrieval data with a foundational model accessed through a foundational model hub for an analysis task using the orchestration layer to generate an analysis response. The method involves transmitting a query response including the analysis response to the application.
A method implements an autonomous hierarchical multi-agent system. The method involves receiving an application prompt from an application. The method further involves executing central instructions of a central agent, corresponding to the application, with a foundational model to process the application prompt, select a specialized agent cluster from a cluster list, and generate a cluster prompt for the specialized agent cluster. The method further involves executing cluster instructions of a cluster agent, corresponding to the specialized agent cluster, with the foundational model to process the cluster prompt, select a domain agent from a domain agent list, and generate a domain prompt for the domain agent. The method further involves executing domain instructions of the domain agent, with the foundational model, based on the domain prompt. The method further involves transmitting an application response to the application, in which the application response is presented by the application.
A system, includes a processing system comprising an artificial intelligence (AI) engine. The processing system is configured to receive a set of data from a data source, divide the set of data into one or more subsets of data, transmit the one or more subsets of data to the AI engine, transmit one or more queries to the AI engine to elicit search and identification of one or more responses based on a data set comprising the one or more subsets of data, wherein the one or more responses include a text-based response and a graphical response associated with the text-based response, and transmit the text-based response and the graphical response to a graphical user interface for presentation on a display of an electronic device comprising the graphical user interface.
G06F 16/909 - Retrieval characterised by using metadata, e.g. metadata not derived from the content or metadata generated manually using geographical or spatial information, e.g. location
G06F 3/0481 - Interaction techniques based on graphical user interfaces [GUI] based on specific properties of the displayed interaction object or a metaphor-based environment, e.g. interaction with desktop elements like windows or icons, or assisted by a cursor's changing behaviour or appearance
A system for monitoring an annulus in a well includes an inductive coupler. The inductive coupler includes a body, a power coil disposed around a first portion of the body, and a telemetry coil disposed around a second portion of the body separate from the first portion. A hole extends within the body, and a sensor is disposed in the hole.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
95.
SYSTEMS AND METHODS FOR KINETIC HYDRATE INHIBITORS REGENERATION
A method including processing an extract stream in one or more KHI processing units to generate a purified product and a process waste, wherein the extract stream includes an extraction solvent and a kinetic hydrate inhibitor (KHI), and the purified product has a higher concentration of the KHI than the extract stream, and processing the purified product in a KHI reformulation unit to generate a reformulated KHI based on a KHI formulation.
A method includes receiving a source stream into a liquid-liquid extractor. The source stream includes a rich mono ethylene glycol (MEG) and a kinetic hydrate inhibitor (KHI) actives. The method also includes receiving an extraction solvent into the liquid-liquid extractor, wherein the extraction solvent has an affinity for the KHI actives. The method also includes separating the source stream into an extract stream and a raffinate stream in the liquid-liquid extractor via a liquid-liquid extraction using the extraction solvent, outputting the extract stream including the KHI actives and the extraction solvent, and outputting the raffinate stream including the rich MEG.
Disclosed is a method comprising: determining a computing platform for modeling source rocks, the computing platform including a database system, a data processing system, and a machine learning engine; generating, using the database system, analyzed graph data; filtering, using the data processing system, the analyzed graph data based on vitrinite reflectance data and thereby generate trainable data; resolving, using the data processing system, data discrepancies within the trainable data and thereby generate resolved data; holistically enhancing, using the data processing system, the resolved data to be compatible with a plurality of subterranean structures and thereby generate training data; applying, using the machine learning engine, the training data to train a subterranean model and thereby generate a trained subterranean model; and testing, using the machine learning engine, the trained subterranean model and thereby generate a prediction report indicating rock characteristics and classification of a source rocks.
G06V 10/82 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using neural networks
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
G06V 10/46 - Descriptors for shape, contour or point-related descriptors, e.g. scale invariant feature transform [SIFT] or bags of words [BoW]Salient regional features
A method for creating a surrogate model using a generative artificial intelligence (AI) model framework includes performing a simulation of a facility using a simulation model to produce a simulation output. The facility may be used to process oil and/or gas. The method may also include receiving first data related to equipment in the facility. The method may also include generating a plurality of surrogate models based upon the simulation output and the first data. The method may also include performing simulations using the surrogate models to produce surrogate outputs that predict the simulation output. The method may also include generating a recommendation based upon the surrogate outputs.
G05B 13/04 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric involving the use of models or simulators
A method including receiving a plurality of constraints related to extraction of hydrocarbons from a subsurface formation, running one or more simulations based on the constraints, determining an interference boundary based on the one or more simulations, wherein the interference boundary includes a distance between fractures where the interactions between the fractures are below a threshold value, organizing results of the one or more simulations into a first dataset associated with distances between the fractures less than the interference boundary and a second dataset associated with distances between the fractures greater than the interference boundary, generating a first predictive model based on the constraints and the first dataset and a second predictive model based on the constraints and the second dataset, generating a surrogate model based on the first predictive model and the second predictive model, and controlling one or more drilling tools based on the surrogate model.
A method includes receiving input data from a receiver operating in a subterranean environment. The method also includes receiving a set of hyperparameters based on the input data, wherein the set of hyperparameters are associated with the reception of the input data in the subterranean environment. Further, the method includes utilizing a Bayesian optimization policy to iteratively select a plurality of observation points from the set of hyperparameters. Further still, the method includes obtaining a performance metric value for each of the selected observation points. Further still, the method includes selecting a hyperparameter from the set of hyperparameters based on the performance metric values. Even further, the method includes generating corrected input data based on the selected hyperparameter.
