A system is provided a composition of produced fluids of production wells extending through an earth formation, the produced fluids having a concentration of lithium. The system may provide a feed material to a lithium extraction process, the feed material comprising flowrates of the produced fluids. The system may utilize a simulation to determine an optimal feed composition to provide to the lithium extraction process to maximize a concentration of lithium in the feed material. The system may adjust flowrates of each of the produced fluids based on the optimal feed composition. Related systems and methods are also disclosed.
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 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
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
3.
METHOD AND SYSTEM FOR PRODUCING HYDROGEN WITH DECREASED ELECTRICITY CONSUMPTION
The invention relates to a method for producing hydrogen via steam electrolysis, the method comprising the following steps: - producing steam (112) by heating liquid water (204); and - electrolysing, in an electrolysis unit (102), at least a portion of the steam (112) to provide a first output stream (116) rich in hydrogen and a second output stream (118) rich in oxygen; characterised in that the steam is produced by at least one heat pump circuit reusing a portion of the heat from at least one of the output streams (116, 118) in order to vaporise the liquid water. The invention also relates to a system (400) implementing such a method.
The invention relates to the coupling of a hydrogenation or oxidation plant (2) and a dihydrogen production plant (3), for transferring (4) heat generated by the hydrogenation or oxidation plant (2) to an input stream of an electrochemical device of the dihydrogen production plant (3) and/or for feeding (100), to said hydrogenation or oxidation plant (2), one or more fluids formed by the electrochemical device.
The invention relates to a high temperature electrolyser comprising interconnectors (4) forming grooves for retaining seals (44, 46). The invention also relates to the corresponding production and assembly methods.
Methods and systems for managing operation of a well are disclosed. The method may include obtaining sonic log data for a geological formation in which the well is positioned. An iterative cross-correlation based reflector tracking process may be performed using the sonic log data to obtain a reflector data package. The reflector data package may include a plurality of points on a reflector and a plurality of dip angles of the reflector for the plurality of points. The reflector data package may be used, at least in part, to operate the well.
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
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
7.
SYSTEM AND METHODOLOGY FOR EVALUATION OF DISTRIBUTED ACOUSTIC AND TEMPERATURE SIGNALS DURING WELL FLOWS WITH HETEROGENEOUS INFLOW AND OUTFLOW PATTERNS
Methods and systems for managing characterization of wells using data acquisitions tools are disclosed. The data acquisition tools may be positioned in portions of wells. While positioned in the wells, the data acquisition tools may be measured. The measurements may be ingested into models and may provide, as output, inferred conditions in the portions of the wells. The models may be created using simulation systems. The simulation systems may allow for conditions that may be present in wells to be simulated, and data acquisition tools to be exposed to the simulated conditions. While exposed to the simulated conditions, the data acquisition tools may be measured to establish associations that may be used to infer conditions that may be present in wells.
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
A system includes a blowout preventer (BOP) having a ram assembly having first and second pistons. The first piston is configured to drive a first ram into a cavity of the BOP and the second piston is configured to drive a second ram into the cavity. The system also includes a motor assembly having first and second motors. The first motor is configured to cause an extension of a first lock to constrain the first piston and the second motor is configured to cause an extension of a second lock to constrain the second piston. The first and second motors are fluidly coupled to each other in a series arrangement via a connector conduit. The connector conduit is configured to flow a motor fluid sequentially through the first and second motors.
A method for determining a status change of one or more reamers in a wellbore includes receiving past surface data from a first time period. The past surface data includes a past flowrate of a fluid being pumped into the wellbore. The fluid flows through a bottomhole assembly (BHA) in the wellbore. The BHA includes the one or more reamers. The method also includes receiving past downhole data from the first time period. The past downhole data includes a past number of rotations per minute of one or more turbines (past TRPM) in the BHA. The method also includes determining a relationship based upon the past surface data and the past downhole data.
A method may include receiving a prompt via a large language model agent in a framework that includes multiple large language model agents; responsive to the prompt, generating one or more agent actions; transmitting the one or more agent actions to one or more of the multiple large language model agents; and, responsive to the transmitting, generating a control action implementable by a controller operatively coupled to one or more pieces of equipment at a field site.
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 rig power supply system may identify a power profile of a drilling rig. A rig power supply system may, based on the power profile, generate an operating profile for the drilling rig, the operating profile including a combination of rig power supply of a rig power supply system and stored energy capacity of an energy storage system.
A rig power management system may identify a power demand of a drilling rig. A rig power management system may when the power demand is greater than a threshold power setpoint, supplementing a rig power supply system with an energy storage system. A rig power management system may when the power demand is less than the threshold power setpoint, maintaining a power generation at an operating power setpoint to charge the energy storage system.
Methods and systems are disclosed that use a temperature sensor integral to a drill bit during drilling. The temperature sensor is configured to measure temperature associated with a cutting element of the drill bit over time during drilling. The temperature sensor is used to generate temperature data representing temperature of the cutting element of the drill bit over time during drilling. The temperature data is processed to determine and monitor at least one condition of the wellbore and/or the drill bit during drilling, such as i) detection of faults or openings or cracks or other geological rock features of the wellbore being drilled, ii) estimation of one or more drilling parameters of the drill bit (such as rate of penetration (ROP), iii) detection of lost cutting element(s), iv) detection of bit balling, and v) detection of drilling efficiency.
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
Aspects of the disclosure provide for using anticorrelation in propagation resistivity logs to detect boundary approaching conditions. Geosteering may be performed based on the detected boundary approaching conditions. The boundary detection and geosteering may be for a high angle well. The anticorrelation may be between attenuation resistivity and phase shift resistivity.
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 41/00 - Equipment or details not covered by groups
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
16.
CUTTING INSERTS FOR USE IN A DOWNHOLE BIT AND METHODS THEROF
A cutting insert may include a base surface and a cutting element. The base surface is configured to be connected to a base of the cutting element. The cutting element including an upper surface. The upper surface includes a vertical most point and a cutting edge, and where the cutting edge has a vertical most portion, and where the vertical most portion of the cutting edge is closer to the base surface than the vertical most point.
A system includes a tube string configured to deploy within a wellbore, where the tube string includes a passage extending along a length of the tube string, and where the passage is configured to route fluid between a downhole location and an up hole location. The tube string also includes passage isolation device including a ball valve disposed within the passage and configured to transition between an open configuration and a closed configuration, where the ball valve is configured to enable a flow of the fluid through the ball valve in the open configuration. The ball valve is also configured to block the flow of the fluid through the ball valve in the closed configuration. The passage isolation device also includes an electronic actuator coupled to the ball valve, where the electronic actuator is configured to actuate the transition of the ball valve between the open configuration and the closed configuration.
The present application relates to a connector (10) designed to establish a fluid connection between two ducts (5, 6) of a high-temperature electrolyser-type electrochemical system. The connector (10) comprises a pipe element (30) and a connecting member (32), each comprising an electrically insulating material such as a ceramic. The present application also relates to an electrochemical system comprising at least one such connector (10).
C25B 1/042 - Hydrogen or oxygen by electrolysis of water by electrolysis of steam
C25B 9/00 - Cells or assemblies of cellsConstructional parts of cellsAssemblies of constructional parts, e.g. electrode-diaphragm assembliesProcess-related cell features
C25B 15/08 - Supplying or removing reactants or electrolytesRegeneration of electrolytes
F16L 23/028 - Flanged joints the flanges being connected by members tensioned axially characterised by how the flanges are joined to, or form an extension of, the pipes the flanges being held against a shoulder
H01M 50/00 - Constructional details or processes of manufacture of the non-active parts of electrochemical cells other than fuel cells, e.g. hybrid cells
H01M 8/04 - Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids
19.
METHODS AND SYSTEMS TO GENERATE COMPONENTS OF THE DIRECTIONAL GRADIENT OF THE SEISMIC WAVEFIELD
System and method operable to estimate directional gradients of a seismic wavefield from seismic data from a seismic survey. The operations include receiving the seismic data describing the seismic wavefield, estimating the directional gradients, from the seismic data, of the seismic wavefield along one or more directions, using the seismic wavefield and the directional gradients to perform an action, creating interpolated data using the seismic wavefield and the directional gradients for interpolation, identifying a subset of the interpolated data based on pre-selected criteria, determining residual data based on a difference between the subset and the seismic wavefield, estimating the directional gradients from the residual data, and displaying the directional gradients.
Aspects of the present disclosure provide a method for extracting minerals from a reservoir zone. The method includes extracting a fluid from the reservoir zone, the fluid including mineral brine and the mineral brine including the minerals, extracting the minerals from the mineral brine and producing a depleted effluent, injecting one or more tracers into the depleted effluent, injecting the depleted effluent with the one or more tracers into the reservoir zone, and monitoring the fluid for the one or more tracers.
The invention relates to a plant for producing dihydrogen, referred to as plant. The plant comprises an electrolyser, arranged to produce dioxygen and dihydrogen from steam, referred to as hot steam, at a temperature higher than 150°C, or water, referred to as hot water, at a temperature lower than or equal to 90°C. The plant further comprises a clinker manufacturing unit. The plant further comprises a heat recovery unit arranged to produce the hot steam or the hot water from gaseous emissions, referred to as hot gases, at a temperature higher than 150°C, emitted by the clinker manufacturing unit.
This disclosure describes a drilling system that uses a resolution transformation system to generate high-resolution target data for one or more types of low-resolution data of a wellbore data log. In various implementations, the resolution transformation system uses a resolution transformation machine learning model that is generated based on high-resolution source data of a different type from the target data and a tool response function associated with the target data. Accordingly, the resolution transformation system efficiently and accurately generates high-resolution target data from the low-resolution target data, which may result in identifying downhole features that would otherwise not be indicated in the low-resolution target data.
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
G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups
23.
ESP PROTECTOR BAG SUPPORT AND GAS PURGING PROTECTOR FOR LOW ANGLE APPLICATION
An electric submersible pump (ESP). The ESP may comprise a bag frame comprising an upper bag frame and a lower bag frame. The ESP may comprise a bag. The ESP may comprise a housing. The ESP may comprise a shaft tube. The ESP may comprise a clamp. The ESP may comprise a bag support with a lower bag support and an upper bag support. The bag support may support an external surface of the bag that is uncovered by the housing, the bag frame, the shaft tube, and the clamps. The lower bag support may comprise a single, complete ring that supports the bag from the clamp to the housing.
A bacterial carbon dioxide immobilization system may inject carbon dioxide in the underground aquifer. A bacterial carbon dioxide immobilization system may inject a nutrient in the underground aquifer. A bacterial carbon dioxide immobilization system may inject carbonate-forming bacteria configured to form a carbonate from the nutrient and carbon dioxide, the carbonate-forming bacteria encapsulated with an encapsulating layer.
An electric submersible pump (ESP) comprising: a head comprising one or more top bearings and one or more sand filters; a long bearing with axial grooves configured to be used with two short sleeves; raised and intermediate seal bodies with long-bearings; an internal relief valve mounted internally inside a seal body; a body positioned above a thrust bearing chamber comprising dual bushings with axial grooves in different bores; and a base with long-bearings.
The invention relates to a high-temperature electrolyser comprising corrugated interconnectors (4) equipped with reinforcing rods (30). The invention also relates to the associated production method.
The invention relates to a modular assembly for a solid oxide electrolysis system for producing hydrogen. The assembly comprises at least one module (1) comprising at least one stack (2) of solid oxide plates positioned in a heat chamber (3), pipes for supplying fluids into the stack (2), pipes for discharging fluids from the stack (2), and at least one fluid-heating device allowing the fluid to reach a temperature that is compatible with the operation of the stack (2). The module (1) comprises a first removable part (10) provided with first connectors (4) for fluid pipes, which part comprises the stack (2) of solid oxide plates positioned in the heat chamber (3), and a second fixed part (11) provided with second connectors (5) capable of being connected to and disconnected from the first connectors (4). The second fixed part (11) comprises a distribution network (13) comprising the fluid supply pipes (14) and fluid discharge pipes (15).
A method includes: generating a synthetic geological formation model, including: receiving relative dip angles, determining a dielectric assumption, a horizontal relative permittivity, a vertical relative permittivity, and a vertical resistivity, and determining respective apparent dielectric permittivity and resistivity, performing 1D inversion, including: generating random geological layer parameters, generating a reference formation model, forward modeling the synthetic geological formation model, generating attenuation and phase-shift logs, generating a 1D inversion model, and generating inverted resistivity and inverted permittivity (EPSI), training a dielectric enhancement model, including: validating the dielectric enhancement model with the apparent dielectric permittivity and resistivity and an enhanced EPSI, training a convolutional neural network (CNN) with the inverted resistivity and permittivity and the relative dip angle, and updating the enhanced EPSI, generating a model prediction for a target geological formation, including: receiving logged values for the target geological formation, and correcting the logged values with the trained dielectric enhancement model.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
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 can include accessing a flow simulation model for a fluid network; receiving parameters for the fluid network; performing one or more flow simulations for the fluid network using the flow simulation model and the parameters to generate results; and generating result constructs, using the results, for optimization of the fluid network.
A safety valve piston seal assembly for safety valve pistons to improve the reliable of safety valve operation. The safety valve piston seal assembly is positioned about a safety valve piston and comprises components which divert a load path to the safety valve piston rather than to susceptible components of the seal assembly. The seal assembly may comprise a metal spring energized seal, an MSE backup ring adjacent the MSE seal and a load transfer assembly. The load assembly comprises a load ring, C-rings and a retaining sleeve. The retaining sleeve holds the two load rings and C-ring in place. The retaining sleeve restricts movement of the load ring.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
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
31.
LARGE LANGUAGE MODEL-BASED WORKFLOW FOR RETRIEVING INFORMATION FROM OIL AND GAS DOCUMENTS
A method for retrieving information from documents includes receiving a plurality of documents. The method also includes splitting each document into chunks. The method also includes applying an embedding model on each chunk. The method also includes storing the chunks and their corresponding embedding models in a vector database. The method also includes receiving a question involving one or more wells. The method also includes determining whether the question is directed to a single one of the one or more wells or multiple of the one or more wells using a large language model (LLM). The method also includes performing a first set of sub-steps in response to the question being directed to the single well, or a second set of sub-steps in response to the question being directed to the multiple wells.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
The invention relates to a hot box (1) of reversible high-temperature SOEC/SOFC electrolysis stacks (2), comprising a tank (10) accommodating at least two stacks, an inlet (14) and an outlet (15) through which first and second fluids (32) can enter and be discharged, said hot box further comprising a first supply pipe (6) for supplying a third fluid to each of said at least two stacks (2), and which extends from outside said tank to a central shaft (60). The hot box comprises sub-pipes (61) for distributing said third fluid, these each extending from the central distribution shaft to an inlet of a stack, said at least two stacks being positioned at equal distances from said central shaft. The hot box also includes discharge channels (62) which extend from the bottom of each of the stacks, to a second discharge pipe that collects a fourth fluid and discharges it out of said tank.
A method for performing core-to-log depth matching includes receiving input data. The input data includes core data and well log data. The method also includes performing an autonomous data preprocessing procedure to standardize the core data and the well log data to determine correlations between the core data and the well log data. The method also includes performing an autonomous outlier removal procedure to address differences in acquisition methods and measurement principles of the core data and the well log data. The method also includes automatically determining normalized cross-correlations between measurements derived from the core data and measurements derived from the well log data. The method also includes automatically shifting the measurements derived from the core data to a new depth position based upon a maximum of the normalized cross-correlations.
A method to perform a seismic survey using one or more source vessels includes enabling shooting from at least two seismic sources at pre-selected time intervals or pre-selected locations. The at least two seismic sources are on the one or more source vessels, and the at least two seismic sources include source technologies that differ from each other. The method also includes measuring wavefields received from the at least two seismic sources. The method also includes associating energy from the wavefields generated by each source with different seismic traces. The method also includes obtaining data from the different seismic traces that are equivalent to different datasets acquired in different surveys using the source technologies that differ from each other.
A method may include receiving a prompt by a generative artificial intelligence engine, where the prompt describes a drilling analysis; responsive to the prompt, generating configuration settings for one or more graphical user interfaces of one or more computational frameworks; and transmitting instructions for rendering at least one of the graphical user interfaces to a display according to its configuration settings.
A method for generating a seismic profile includes receiving input data. The method also includes generating seismic features based upon the input data. The method also includes extracting seismic tiles and/or sub-volumes from the seismic features. The method also includes training a 2D or 3D model based upon the seismic features and the seismic tiles and/or sub-volumes to produce a trained 2D or 3D model. The method also includes generating the seismic profile using the trained 2D or 3D model.
A method for detecting hydrocarbon-related seismic anomalies includes receiving first input data. The method also includes training a plurality of subnet models based upon the first input data to produce a plurality of trained subnet models. The method also includes building a multi-modal foundation model using the trained subnet models. The method also includes receiving second input data. The method also includes generating a multi-modal feature space using the multi-modal foundation model based upon the second input data.
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
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
38.
AI-ASSISTED HYDROCARBON ANOMOLY IDENTIFICATION USING OPTIMIZED DEEP LEARNING TASK SPECIFIC WORKFLOW
A method for detecting hydrocarbon-related seismic anomalies includes receiving input data related to a reservoir. The method also includes training an artificial intelligence (AI) model based upon the input data to produce a trained AI model. The method also includes classifying seismic anomalies in the input data using the trained AI model to produce classified seismic anomalies. The method also includes generating exploration tasks using the trained AI model based at least partially upon the classified seismic anomalies. The exploration tasks include pay maps, confidence attributes, and/or risk resource determinations.
A drill bit includes cutting elements and a displacement sensor deployed on a drill bit body. The displacement sensor includes an engagement piston disposed to translate axially in a sensor housing. The engagement piston includes an inner plunger and an opposing outer engagement element configured to engage a subterranean formation and is biased outward from the sensor housing. The displacement sensor further includes a position sensor configured to sense an axial position of the engagement piston in the sensor housing. An electronic controller is configured to determine a measured displacement from the sensed axial position of the engagement piston. The displacement sensor may enable depth of cut and rate of penetration measurements to be made while drilling.
E21B 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
E21B 10/48 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of core type
40.
SYSTEMS AND METHODS FOR PREDICTING WELLBORE STIMULATION PERFORMANCE OF ACID JETTING THROUGH PRE-PERFORATED LINERS
The present disclosure relates to systems and methods for predicting wellbore stimulation performance of acid jetting through pre-perforated liners. In particular, the methods presented herein include collecting data relating to a wellbore stimulation operation performed subsurface in a wellbore, and utilizing a physics-based model to predict an effect of jetting on efficiency of a reactive fluid during the wellbore stimulation operation based at least in part on the collected data. In addition, experimental and field treatment data, real-time telemetry, production logs, flow quantification logs or distributed sensing (e.g., temperature, acoustic, strain, and so forth) results may be used to calibrate tuning parameters of the physics-based model, which may be adjusted based on data analytics and machine learning methods.
E21B 43/27 - Methods for stimulating production by forming crevices or fractures by use of eroding chemicals, e.g. acids
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
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 health status and monitoring system may receive status information for a plurality of subsystems of the fluid processing facility, the status information including at least one of time-series data, daily reports, maintenance records, inspection records, equipment runtime, equipment uptime, control room reports, shift reports, or laboratory samples. A health status and monitoring system may apply a current status model to the status information, the current status model generating a health status for the fluid processing facility, the health status incorporating a subsystem status of the plurality of subsystems.
A system includes a valve cartridge, including a body defining a fluid flow path extending from an oil inlet to an oil outlet. The oil inlet is configured to be fluidly coupled to a volume disposed about a piston. The oil inlet is configured to receive oil from the volume disposed about the piston and direct the oil along the flow path. The toe valve cartridge further includes a first membrane disposed along the flow path, downstream of the oil inlet. The first membrane is configured to rupture when exposed to a pressure and a second membrane disposed along the flow path, downstream of the first membrane. The valve cartridge is configured to direct the oil along the flow path, through the ruptured first membrane, through the ruptured second membrane, and out of the valve cartridge via the oil outlet.
E21B 34/10 - Valve arrangements for boreholes or wells in wells operated by control fluid supplied from outside the borehole
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 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
A method may include receiving data for drilling of a borehole in a subsurface environment according to a borehole trajectory for a target well at a field location in a basin; accessing offset well data for wells in the basin using at least a portion of the data, where the offset well data include identified formation tops with respect to well depth for a number of formations within the basin and mechanical specific energy drilling data with respect to well depth; aligning the offset well data using the formation tops to generate aligned offset well data that specify one or more drilling zones based on the mechanical specific energy drilling data; and performing the drilling based at least in part on the aligned offset well data.
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
44.
METHOD TO EXTRACT COLOR AND TEXTURE INFORMATION FROM ROCK PARTICLE INSTANCE IMAGES
Systems and methods are provided to extract features (e.g., colors, textual features) from arbitrary shaped and sized images by implementing global average pooling (GAP) and partial convolution in an autoencoder (AE) for analysis of the images. A global average pooling (GAP) layer may be used at the last layer of the encoder of the AE to make the feature rotation and translation invariant and scale equivariant. In addition, partial convolution may be used in the encoder to logically ignore the invalid pixels (e.g., background, image error, other object) or any pixel (e.g., in any area) in the images.
G01N 15/0227 - Investigating particle size or size distribution by optical means using imagingInvestigating particle size or size distribution by optical means using holography
G01N 21/84 - Systems specially adapted for particular applications
A method can include receiving queries for a well work program; responsive to the queries, retrieving data from a database to populate a well work program template; generating a graphical user interface based on the populated well work program template; and, responsive to interactions with the graphical user interface, generating a well work program file that specifies actions to perform the well work program.
G06Q 10/063 - Operations research, analysis or management
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
Methods and apparatus are described herein for recovering an element of interest from an aqueous source. Methods described herein include measuring a first conductivity of a first aqueous material using a conductivity sensor; performing an operation on the first aqueous material to change a concentration of an element of interest of the first aqueous material and yield a second aqueous material; measuring a second conductivity of the second aqueous material using a conductivity sensor; comparing the first conductivity, or a first value of a variable derived from the first conductivity, with the second conductivity, or with a second value of the variable derived from the second conductivity; and modifying a parameter of the operation based on the comparison. Methods are also described herein for recovery of elements of interest from aqueous sources using simulated moving beds processes.
A system may include a CO2 capture module, including a capture unit for capturing CO2 from a gas using a capture material and a regeneration unit for unloading the CO2 from a loaded capture material and regenerating said loaded capture material using heat. A system may include an energy module for producing electrical power and heat using solar energy, wherein at least a portion of the heat produced in the energy module is used in the regeneration unit.
B01D 53/96 - Regeneration, reactivation or recycling of reactants
F24S 10/30 - Solar heat collectors using working fluids with means for exchanging heat between two or more working fluids
F24S 60/00 - Arrangements for storing heat collected by solar heat collectors
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 estimating a mechanical property of a subterranean formation includes engaging the formation with an engagement assembly deployed on a downhole tool to make engagement measurements while rotating the downhole tool in the wellbore. The mechanical property of the formation may be estimated from the engagement measurements. The mechanical property may include a modulus, a strain profile, or a formation integrity.
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
The disclosed methods include: generating a geological model; sampling captured geological data to generate sampled data; evaluating, using an objective function, the sampled data to determine a parameter range for the geological model; deploying, based on the parameter range, a machine learning unsupervised clustering of datapoints comprised in the sampled data to generate seeds data; and ranking, based on the seeds data, two or more rock physics parameters of the geological model. The method further comprises: stochastically optimizing the geological model based on the seeds data and the determined parameter range to generate model performance data for the geological model; calibrating, based on the model performance data, the two or more parameters of the geological model to generate a calibrated geological model; and generating, based on the calibrated geological model, a multi-dimensional report indicating elastic property predictions for each lithology comprised in a reservoir associated with the resource site.
G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
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 includes receiving formation model data corresponding to characteristics of a formation, receiving at least one drilling parameter corresponding to an attribute related to a well in the formation, generating a synthetic response based upon the formation model data and the at least one drilling parameter, undertaking channel selection based on the synthetic response as training data, wherein the channel selection comprises a set of data channels of a logging tool of the well that prioritizes a predetermined portion of measurements to transmit from the logging tool, training a machine learning system into a trained machine learning system utilizing the training data comprising the channel selection corresponding to the synthetic response as a matched pair of inputs for the machine learning system, and generating a final model as the trained machine learning system via the training of the machine learning system.
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 47/12 - 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 can include receiving a query from a drilling operations framework; enhancing the query by retrieving data from a database to form an enhanced query; generating a response to the enhanced query using a large language model; and processing the query, based at least in part on the response, using the drilling operations framework to formulate a control action for drilling operations.
Systems and methods for exacting elements of interest, such as lithium, from an aqueous material are described herein. The systems generally use multiple vessels with selective media in each vessel to accomplish extraction of the element of interest. The vessels are operated in cyclic, permuted fashion to move between absorption and desorption operations by routing flows of streams for accomplishing such operations among the vessels in programmed ways. Sensors configured to detect total dissolved solids, or a parameter related to total dissolved solids, are used to detect endpoints for mode switching and to ascertain other aspects of system performance.
B01D 15/08 - Selective adsorption, e.g. chromatography
C22B 3/24 - Treatment or purification of solutions, e.g. obtained by leaching by physical processes, e.g. by filtration, by magnetic means by adsorption on solid substances, e.g. by extraction with solid resins
A system and method for predicting formation properties is described. For example, a computing device may receive deep directional resistivity (DDR) measurement data from one or more DDR sensors. The computing device may apply a formation property prediction model to the DDR measurement data, the formation property prediction model pretrained to identify predicted formation parameters based on input DDR data, formation properties of the input DDR data, and tool parameters. The computing device may receive the predicted formation parameters for a subsurface beyond the wellbore in response to applying the formation property prediction model to the DDR measurement data.
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 47/12 - 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
54.
SYSTEMS AND METHODS FOR DETERMINING DOWNLINKS FOR TRANSMITTING TO A DOWNHOLE TOOL
In some embodiments, a method of implementing an operation of a downhole tool within a wellbore includes identifying a tool command for a downhole tool to change a current state of the downhole tool to a target state. The method further includes determining, from a set of candidate downlink commands, a set of one or more downlink commands associated with executing the tool command. The method further includes generating a downlink sequence of one or more downlinks for communicating the set of one or more downlink commands to the downhole tool. The method further includes. providing the downlink sequence for transmitting to the downhole tool
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 may include receiving data from a pump system at a field site; processing the data to generate card format data; detecting an operational condition of the pump system using a machine learning model and the card format data; and, responsive to the detecting, controlling operation of the pump system at the field site.
A MSE-UCS correlation model of one or more reference wells is based on drilling parameters and well log data. The MSE-UCS correlation model is then used to generate a proxy mechanical earth model of an additional well being drilled using the drilling parameters of the additional well.
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 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
57.
USING A DEEP NEURAL MODEL TO GENERATE JOINT QUALITY SCORES FOR A CASING CONNECTION
A casing installation manager may obtain a training dataset including a plurality of torque-turns datasets for a plurality of casing joint connections. Each of the plurality of torque-turns datasets may include a joint quality score for an associated casing joint connection of the plurality of casing joint connections. A casing installation manager may train, using the training dataset, a deep learning model to generate a new joint quality score for a new torque-turns dataset.
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 19/16 - Connecting or disconnecting pipe couplings or joints
A method can include receiving data for field operations using equipment at a site, where the equipment includes a downhole tool on a tool string disposed in a borehole in a geologic environment and a mud pulse telemetry system; determining control parameters for the mud pulse telemetry system using at least a portion of the data and a trained machine learning model; and controlling the mud pulse telemetry system using the control parameters.
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 wellbore production system includes a production tubing positioned within a wellbore and an electrical submersible pump (ESP) assembly positioned within the production tubing. The ESP assembly is a rigless ESP assembly that is conveyable within the production tubing by a conveyance line. The ESP assembly includes a high-speed helicoaxial pump a motor for driving the helicoaxial pump. A power transmission line extends from a surface of the wellbore outside of the production tubing and connects through the production tubing to the motor. The wellbore production system includes a gravity-assisted gas separator connected to the production tubing and connected to an intake of the ESP assembly.
A method for monitoring, predicting, and projecting a health status of a downhole tool in real-time includes determining whether a selected bottom hole assembly (BHA) run is performed using a drillstring operation or a coiled tubing drilling (CTD) operation. The BHA run includes a BHA in a wellbore, and the BHA includes a downhole tool. The method also includes receiving current parameters for the selected BHA run in a selected well. The parameters include (1) current first parameters that are independent of a performance of the selected BHA run using the drillstring operation or the CTD operation, and (2) current second parameters that depend upon whether the selected BHA run is performed using the drillstring operation or the CTD operation. The method also includes predicting a future health status of the downhole tool based upon the current first parameters and the current second parameters.
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
61.
STOCHASTIC WORKFLOW FOR GEOLOGICAL FAULT SEAL ANALYSIS IN CARBONATE-HOSTED RESERVOIRS
Certain aspects of the disclosure provide a method for fault seal analysis. The method generally includes identifying a fault plane in a subsurface model; determining a plurality of facies juxtaposition types for the fault plane; estimating a fault rock permeability range for each facies juxtaposition type; generating a plurality of candidate fault plane permeability scenarios, wherein for each candidate fault plane permeability scenario, a candidate fault plane permeability property is assigned to each facies juxtaposition type using a simulation and the fault rock permeability range estimated for the respective facies juxtaposition type; and for each candidate fault plane permeability scenario of one or more candidate fault plane permeability scenarios of the plurality of candidate fault plane permeability scenarios, determining fault seal property(ies) for the fault plane using the candidate fault plane permeability properties assigned to the plurality of facies juxtaposition types for the respective candidate fault plane permeability scenario.
A method for predicting buckling behavior in a torque and drag analysis of a tubular string in a wellbore includes performing a first finite element analysis (FEA) on the tubular string. The method also includes determining one or more first properties of the tubular string based upon the first FEA. The method also includes identifying a. possible buckling zone in the tubular string based upon the one or more first properties. The method also includes splitting the possible buckling zone into a plurality of segments. The method also includes performing a second FEA on one or more of the segments. The method also includes determining one or more second properties of the tubular string based upon the second FEA. The method also includes comparing the one or more first properties of first FEA to the one or more second properties of second FEA to identify incremental changes therebetween.
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 47/007 - Measuring stresses in a pipe string or casing
A method may include receiving data acquired by a downhole tool of a tool string disposed at least in part in a borehole in a subsurface region; predicting a position of a formation top in the subsurface region using a trained machine learning model and at least a portion of the data; and controlling operation of the tool string based at least in part on the position of the formation top in the subsurface region.
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
The invention relates to the coupling of a metallurgical plant (2) to a dihydrogen production plant (3), for transferring (4) heat produced by the metallurgical plant (2) to an input stream of an electrochemical device of the dihydrogen production plant (3) and/or for feeding (100) to the metallurgical plant (2) one or more fluids formed by the electrochemical device.
A wellbore fluid includes an aqueous base fluid, and a fluid loss material formulated and configured to form a filtercake on surfaces of an earth formation responsive to exposure to a wellbore pressure. The fluid loss material includes at least one polymer, and a bridging material including a fatty acid salt of at least one of an alkali metal, an alkaline metal, ammonium, quaternary ammonium, a Group IIIA element, a Group IVA element, a Group VA element, a Group IB element, a Group IIB element, or a Group VIIB element of the periodic table, the bridging material comprising an oil-soluble material formulated and configured to dissolve out of the filtercake to form channels in the filtercake. Related methods and wellbore fluids are disclosed.
C09K 8/12 - Clay-free compositions containing synthetic organic macromolecular compounds or their precursors
C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
C09K 8/90 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
66.
COILED TUBING STRING MISSION PROFILE, DESIGN, AND OPTIMIZATION TOOL
Systems and methods presented herein are configured to optimize the design and validation of coiled tubing strings. For example, a processing workflow may include generating a mission profile for a coiled tubing (CT) string for deployment in a well based on CT analytics. The processing workflow may also include creating a CT string design for the CT string based at least in part on a plurality of operational parameters of the well. The CT string design of the CT string defines a plurality of physical characteristics of the CT string. The processing workflow may further include adjusting one or more of the plurality of physical characteristics of the CT string design of the CT string based at least in part on the generated mission profile for the CT string and a predicted life cycle of the CT string.
A system and method of monitoring a downhole tool implemented in a wellbore that include identifying, from surface parameters, a surface downlink sent from a surface of the wellbore to the downhole tool. The surface downlink indicates a downlink command for the downhole tool to implement. The system and method further include confirming that the downhole tool received the surface downlink based on comparing downhole telemetry data received from the downhole tool to the surface downlink. The system and method additionally include, determining a status of the downhole tool indicated by the surface downlink based on confirming that the downhole tool received the surface downlink.
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 47/12 - 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 sealing a wellbore is provided. The method includes positioning a tool including a radiation emitting device in a wellbore at a desired depth, emitting electromagnetic radiation at one or more frequencies, emitting the electromagnetic radiation includes emitting the electromagnetic radiation in a radial direction towards geological material disposed in the wellbore, melting the geological material with the electromagnetic radiation, and sealing at least a portion of the wellbore with the melted geological material.
Methods and related systems for drilling a subterranean wellbore includes rotating a bottomhole assembly (BHA) to drill the wellbore. The BHA includes a cutting tool and at least one sensor. The at least one sensor is configured to make measurements while drilling. These measurements are processed to compute a magnetic field profile, which is further processed to identify and characterize a signature or pattern in the magnetic field profile that is representative of a target well proximate to the wellbore being drilled. At least one of a distance or a direction to the target well can be computed based on characteristics of the signature or pattern in the magnetic field profile. The computed distance or direction to the target well can be used to control the direction of drilling of the wellbore.
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 47/01 - Devices for supporting measuring instruments on drill bits, pipes, rods or wirelinesProtecting measuring instruments in boreholes against heat, shock, pressure or the like
This disclosure relates to systems and methods with multiple sensors located in different zones of a hydrocarbon production system. The multiple sensors are configured to capture parameters about flow through multiple zones of a wellbore. The system also includes a processor that is configured to obtain data about a multiphase flow through the plurality of zones of the wellbore of the hydrocarbon production system from the multiple sensors and to solve an interpretation problem for a first unknown in a bottommost zone. The processor is configured to use a value for the first unknown in the bottommost zone to solve for a second unknown in an upper zone that is above the bottommost zone in the wellbore of the hydrocarbon production system. The processor is configured to change control parameters of the hydrocarbon production system based at least in part on the first unknown and the second unknown.
A roller cone may include a innermost region having roller cone cutting elements arranged thereon such that the cutting elements may be closer to a radial axis of a drill bit. A roller cone may include a central region having roller cone cutting elements arranged thereon. The central region of a roller cone may also include multiple zones where the cutting element density within the central region and/or zones may vary between zones and/or regions. The cutting element density may be no less than 75% greater in one zone /or region than the cutting element density of another zone/or region.
This application relates to a downhole system that uses a transition detection system to determine transitions between downhole activities or operations for a wellbore based on wellbore measurement data. In various implementations, the transition detection system uses a transition identification machine learning model to generate downhole transition types between downhole operations from wellbore measurement data. Additionally, the transition detection system identifies errors and inaccuracies with activity transitions reported in a downhole operation report based on comparing the downhole operation report to the determined transition times generated by the transition identification machine learning model.
A method of determining eccentricity of a tubular within a wellbore includes transmitting a sonic signal and receiving sonic waveforms based on detecting the sonic signal with sonic receivers positioned azimuthally around a sonic measurement tool. The sonic waveforms each include a tubular interference mode reflected and/or refracted from the tubular, and a casing interference mode reflected and/or refracted from a casing of the wellbore. The method includes generating an eccentricity waveform plot by combining the sonic waveforms and removing a monopole component, and generating an arrival time curve of the sonic waveforms to determine an earliest arrival time of the casing interference mode of one of the sonic waveforms. An eccentricity direction is determined as the azimuthal position of the earliest arrival time, and an eccentricity magnitude is determined with a tubular-eccentricity model based on the earliest arrival time.
An autonomous multiphase boosting (AMB) system (1) comprising an inlet pipe (30), equipped with a phase determination assembly (20), configured to determine a gas volume fraction and a mass rate of at least one phase in a multiphase inlet flow flowing in the inlet pipe; a multiphase pump (40); a fluid separator (50), configured to receive a multiphase boosted flow outputted by the multiphase pump and to separate a gas phase from a liquid phase of the multiphase booster flow, the liquid phase being outputted by a liquid outlet (53) to form a liquid flow; a return pipe (70), connecting the liquid outlet to the inlet pipe, the return pipe being equipped with at least a return valve (71); and a controller (80), configured to control the return valve based on the gas volume fraction determined by the phase determination assembly.
An electrical submersible pump system includes an electrical submersible pump (ESP) and a motor connector assembly (MCA) coupled to the ESP, such that the MCA includes an upper annular body including an outer circumferential annular surface, a lower annular body coupled to the upper annular body via a threaded connection, and a bearing sleeve assembly that includes a bearing sleeve, such that the bearing sleeve assembly is configured to mount on the outer circumferential annular surface.
Aspects of the present disclosure provide a method for insulating a cable. The method including applying a plurality of layers of an insulating material around a portion of a conductor of a cable, at least one layer of the plurality of layers including a first visual indicator, at least another layer of the plurality of layers including a second visual indicator, curing the plurality of layers to form an insulation layer having an outer diameter, removing a portion of the outer diameter of the insulation layer to reduce the outer diameter of the insulation layer to a desired diameter while maintaining a desired insulation layer thickness, and determining the desired diameter has been reached and the desired insulation thickness has been maintained based on an appearance of one of the first visual indicator or the second visual indicator.
A wellbore fluid includes a continuous phase comprising an oleaginous fluid, a discontinuous phase comprising a non-oleaginous fluid, an emulsion of the discontinuous phase in the continuous phase, at least one emulsifier disposed around droplets of the discontinuous phase, at least one gelling material comprising at least one of xanthan gum, scleroglucan gum, gellan gum, carrageenan gum, or curdlan gum, and at least one crosslinker dispersed within the non-oleaginous fluid of the discontinuous phase. Related methods and treatment fluids are also disclosed.
C09K 8/68 - Compositions based on water or polar solvents containing organic compounds
C09K 8/90 - Compositions based on water or polar solvents containing organic compounds macromolecular compounds of natural origin, e.g. polysaccharides, cellulose
C09K 8/588 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
C09K 8/32 - Non-aqueous well-drilling compositions, e.g. oil-based
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
The present disclosure relates to shaped charge. The shaped charge includes an explosive component having a first density and a first mechanical strength. The shaped charge also includes a liner member having a second density and a second mechanical strength. Further, the shaped charge includes an intervening liner member having a third density and a third mechanical strength. The intervening liner member is disposed between the explosive component and the liner member. The intervening liner member has one or both of: the third density being between the first density and the second density; and the third mechanical strength being between the first mechanical strength and the second mechanical strength.
Methods for geothermal well planning and development are provided. This includes: installing fiber optic cables that extend within a plurality of shallow wells, wherein the fiber optic cables support both DTS measurements and DAS measurements; connecting DTS interrogators to the fiber optic cables and configuring the DTS interrogators to measure temperature profiles in the plurality of shallow wells over time; determining planned location of one or more geothermal wells that access a geothermal reservoir from the measured temperature profiles; selecting at least one shallow well to be used for DAS measurements; at each selected shallow well, disconnecting the DTS interrogator from the fiber optic cable at the shallow well and connecting a DAS interrogator to the fiber optic cable at the shallow well; and configuring the DAS interrogator at each selected shallow well to measure an acoustic profile in the selected shallow well over time.
Methods and systems are provided for automated closed-loop control of drilling trajectory during directional drilling to a geological target, which employ a surface-located predictive controller that interfaces to and cooperates with a downhole trajectory control system to automatically control the drilling direction of a drilling tool during the directional drilling. The predictive controller is configured to receive data representing a new reference trajectory for a given measured depth and generate output data representing a sequence of set-points for the new reference trajectory. The predictive controller is further configured to communicate the output data to the downhole trajectory control system to automatically control the drilling direction of the drilling tool to follow the new reference trajectory.
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
An assembly for use in an electrical submersible pump includes a thrust runner. A shaft extends through the thrust runner. A plurality of grooves is formed in an exterior surface of the shaft. A ring disposed around the shaft includes an interior surface defining a bore. The interior surface includes a plurality of ribs protruding into the bore. Each rib is engaged with a corresponding groove of the plurality of grooves. A collar is disposed around the shaft and the ring. The collar includes a flange engaged with the thrust runner between the thrust runner and the ring.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
82.
METHODS FOR SELECTION OF COMPOSITION AND CONCENTRATION OF A CORROSION INHIBITOR PACKAGE USED IN STIMULATION OF SUBTERRANEAN FORMATIONS INVOLVING ACID-CONTAINING FLUIDS
The present disclosure relates to a method for stimulating a subterranean formation that includes selecting a wellbore for an acid stimulation treatment and initial pumping schedule using a wellbore treatment fluid system; obtaining information on metal used for pipe in the wellbore and a maximum corrosion rate threshold and/or a pitting index threshold to perform the acid stimulation treatment; determining composition and concentration of a corrosion inhibitor package for the wellbore treatment fluid system to obtain a corrosion rate and/or a pitting index of surfaces of the metal; updating the pumping schedule based on the determined composition and concentration of the corrosion inhibitor package; and performing hydraulic acid fracturing or an acidizing treatment using the updated pumping schedule.
A method including obtaining measurements of one or more first parameters of a packer during an actuation of the packer in a borehole, obtaining measurements of one or more second parameters related to a geometrical change in the borehole caused by the actuation of the packer, and analyzing a plurality of first and second parameters, a plurality of derivatives of the first and second parameters, or a combination thereof to estimate at least a static bulk modulus (K) of a geological formation surrounding the borehole.
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 33/1295 - PackersPlugs with mechanical slips for hooking into the casing actuated by fluid pressure
E21B 33/126 - PackersPlugs with fluid-pressure-operated elastic cup or skirt
A wireline cable with zinc-coated steel armor wires exposed at its exterior, is protected from corrosion by fluid, such as drilling fluid, in a wellbore by application of a coating of a viscous liquid composition, which may be a thixotropic grease, onto the exposed armor wires. The viscous liquid composition includes a viscous carrier and at least one substance which is an oxygen scavenger. The cable may also be protected by application of such a coating as it is withdrawn from a wellbore and rewound onto a storage drum.
A method can include receiving dielectric data from a downhole dielectric tool of a drillstring disposed in a borehole in a target material that includes a target material boundary between the target material and one or more other materials; generating a geosteering command, based at least in part on the dielectric data, that calls for orienting a drill bit of the drillstring with respect to the target material boundary; and issuing the geosteering command to a geosteering actuator of the drillstring.
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 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
Systems and methods of the present disclosure includes a mixer configured to mix air and hydrocarbons and a burner configured to receive the mixed air and hydrocarbons and to generate syngas. The system also includes a cooling system configured to receive the syngas and to cool the syngas to form cooled syngas. The system further includes a collector configured to collect carbon from the cooled syngas as soot. Moreover, the system includes a flare stack configured to receive the cooled syngas and to burn off at least part of the cooled syngas.
A method of evaluating an operation of a downhole motor implemented in a wellbore includes receiving a first set of downhole data associated with the operation of the downhole motor at a first flowrate and generating a flowrate-independent power curve for the downhole motor based on the first set of downhole data. The method further includes, based on the flowrate-independent power curve, determining a second set of downhole data associated with the operation of the motor at a second flowrate.
The present disclosure relates to a shaped charge. The shaped charge includes an explosive component and a liner member coupled to the explosive component. The explosive component and the liner member emit a perforating jet based on ignition of the explosive component. The liner member has a planar symmetric portion that is planar symmetric along an axial length of the planar symmetric portion relative to planes perpendicular to a direction of the emitted perforating jet.
A method can include receiving data from field equipment at a number of well sites via a number of local edge devices; processing the data to determine optimal field operation parameters for field operations at the number of well sites; and controlling the field operations using the determined optimal field operation parameters.
Embodiments presented provide for a connection between high power sources to downhole equipment. In embodiments, methods and apparatus are presented to allow connection of power sources in hazardous environments, such as gaseous environments containing explosive hydrocarbons.
A method of analyzing torque and drag of a drill string in a wellbore includes receiving wellbore data including a trajectory of the wellbore, and receiving drill string data for the drill string, at least a portion of the drill string including an inner string positioned inside of the drill string. The method includes generating a virtual wellbore associated with the inner string based on an inner diameter of the drill string and based on the trajectory of the wellbore, and determining a set of inner forces for the inner string including an axial force based on the weight of the inner string and a set of contact forces between the inner string and the virtual wellbore. The method includes identifying a set of normal forces between the drill string and the wellbore based on simulating the inner forces as applied forces to the drill string.
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 47/007 - Measuring stresses in a pipe string or casing
A system and method may include receiving data acquired by a downhole tool of a tool string disposed at least in part in a borehole in a subsurface region. The system and method may also include inverting the data using a trained machine learning model to generate a structural feature of the subsurface region. The system and method may further include controlling operation of the tool string based at least in part on the structural feature of the subsurface region.
A method of predicting behavior of a downhole tool implemented in a wellbore includes receiving geometry data associated with the downhole tool. The geometry data may indicate a bend angle of the downhole tool based on the tool being bent at a bend point. The method further includes, based on the geometry data, generating a simplified model of the downhole tool including determining an effective bend point and an effective bend angle based on the longitudinal axis of the wellbore. The method further includes receiving operational parameters for the downhole tool and simulating an operation of the downhole tool based on applying the operational parameters to the simplified model. The method further includes determining one or more behavior characteristics of the downhole tool based on the simulation.
A method comprising validating a carbon dioxide injection operation plan at a carbon dioxide injection site, which comprises creating a first simulation model to simulate flow from the wellhead to a downhole environment and creating a second simulation model to simulate flow dynamics in a reservoir. The method further comprises conducting a carbon dioxide injection test operation based on the carbon dioxide injection plan at the carbon dioxide injection site and monitoring the carbon dioxide injection operation, which comprises measuring real-time data from the wellhead and the downhole, comparing the real-time data with the first simulation model, identifying risks from the comparison between the collected data in the first simulation model, and adjusting the carbon dioxide injection operation and based on the identified risks.
A method can include receiving by a computational device at a wellsite, real-time, time series data from a pump system operating at the wellsite, where the wellsite includes a wellbore in contact with a fluid reservoir; using the computational device, processing a portion of the time series data to generate feature values as input to a trained machine learning model to detect pump system behavior indicative of a forthcoming performance issue of the pump system; and issuing a signal responsive to detection of the pump system behavior to mitigate the forthcoming performance issue of the pump system.
E21B 47/008 - Monitoring of down-hole pump systems, e.g. for the detection of "pumped-off" conditions
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 technique facilitates drilling of a borehole by simplifying alignment between a running tool and a seal rotating system. According to an embodiment, the running tool is connected into a drill string. The drill string is then used to move the running tool linearly within the seal rotating system until engagement of an alignment mechanism occurs. With continued linear movement, the alignment mechanism automatically causes relative rotation between the running tool and the seal rotating system until a desired alignment position is achieved. The seal rotating system may then be secured to the running tool via threaded fasteners or other suitable fastening mechanism.
An Influx Management Envelopes (IME) for MPD through a cloud-based solution is generated, simplifying the process for routine application in drilling operations and providing parallel computing to enhance the efficiency of IME generation by parameterizing various influx scenarios. Utilizing a transient multiphase flow engine, the study establishes kick tolerance thresholds for safe influx volume determination. The analysis includes assessing associated risks during kick circulation using MPD system. Parallel computing facilitates faster computations and improved scalability. The combined approach integrates simulation results into an operational envelope for safer decision-making. The IME may be determined considering company well control policies, for adherence to established guidelines and maintain a consistent and standardized approach to well control practices. Collaborative workflows facilitate seamless teamwork, communication, and coordination. The integration of a collaborative framework enables effective sharing of expertise and contributes significantly to a comprehensive understanding of drilling operations.
A milling bit valve is disclosed for improved debris collection within a wellbore. The check valve can be part of a debris removal tool that includes a motor, pump, gearbox, bailer, milling bit, check valve, and rotational shafts. In an example, on its uphole end, the milling bit can be coupled with the check valve. On its downhole end, the milling bit can be configured for debris removal with cutting edges. The downhole end can also include openings that provide access to an internal cavity of the milling bit. The internal cavity can extend the entire length of the milling bit. This allows the pump to pull drilling fluid into the bailers through the milling bit and check valve. As a result, the debris removal tool can simultaneously remove obstructions in a wellbore and collect debris from the obstruction removal.
E21B 29/00 - Cutting or destroying pipes, packers, plugs or wire lines, located in boreholes or wells, e.g. cutting of damaged pipes, of windowsDeforming of pipes in boreholes or wellsReconditioning of well casings while in the ground
E21B 31/00 - Fishing for or freeing objects in boreholes or wells
E21B 10/60 - Drill bits characterised by conduits or nozzles for drilling fluids
99.
METHOD OF ACCELERATING THERMODYNAMIC PROCESS PARAMETER COMPUTATION FOR CARBON CAPTURE, UTILIZATION, AND STORAGE SYSTEMS
Certain aspects of the disclosure provide a method for carbon capture, utilization, and storage (CCUS) process simulation. The method generally includes processing, with a first sub-model of a machine learning (ML) model, input features to generate a first thermodynamic process parameter for a first thermodynamic component, wherein the input features comprise one or more thermodynamic properties; processing, with a second sub-model of the ML model, the input features to generate a second thermodynamic process parameter predicted for the first thermodynamic component; selecting, by the ML model, a final thermodynamic process parameter for the first thermodynamic component as: the first thermodynamic process parameter when the first thermodynamic process parameter is greater than a first threshold; or the second thermodynamic process parameter when the first thermodynamic process parameter is less than the first threshold; and providing as a first output from the ML model the selected final thermodynamic process parameter.
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
The invention relates to a facility (1) for producing dihydrogen, the facility comprising a water purification device (2), a heating device (3) for converting the purified water into steam, and an electrolyser (4) configured to produce at least one stream of dihydrogen from the steam. The heating device (3) is preferably configured to recover waste heat. The invention also relates to a corresponding method.
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