A computer-implemented method includes identifying a repository of equipment documents in an unstructured format for oil and gas equipment, generating text-based equipment documents in a computer-readable text format, and generating a vector index of vector embeddings from the text-based equipment documents. The method includes, in response to receiving an equipment content request, providing the vector index and an equipment content prompt to a generative AI model for instructing the generative AI model to generate an equipment content response using the vector embeddings from the vector index. Based on receiving the equipment content response from the generative AI model, the method includes providing the equipment content response to a client device.
Methods and apparatus for treating solids surfaced from a subterranean well are described herein. The solids are irradiated using a combination of radiation from different spectral regions, including infrared, RF, microwave, and visible wavelengths. Moisture content, hydrocarbon content, or both, of the irradiated solids is measured, and a characteristic of the radiation is adjusted based on the measurement.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
C09K 8/58 - Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
E21B 43/38 - Arrangements for separating materials produced by the well in the well
E21B 43/34 - Arrangements for separating materials produced by the well
C02F 1/30 - Treatment of water, waste water, or sewage by irradiation
C02F 103/36 - Nature of the water, waste water, sewage or sludge to be treated from the chemical industry not provided for in groups from the manufacture of organic compounds
3.
AUTOMATIC STRATIGRAPHIC SEQUENCE IDENTIFICATION FOR MARKERS CONDITIONING
A method for performing a markers sequence analysis for a plurality of wells includes receiving input data including markers corresponding to a plurality of wells. The method also includes creating clusters of the wells in response to a subset of the markers being similar. The method also includes determining a transition matrix corresponding to each cluster. The method also includes extracting a sequence from the transition matrix of each cluster. The method also includes merging the sequences to produce merged sequences.
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 47/022 - Determining slope or direction of the borehole, e.g. using geomagnetism
G06F 17/18 - Complex mathematical operations for evaluating statistical data
A method for identifying, ordering, and dull-grading a plurality of cutters on a drill bit includes capturing a plurality of frames of a plurality of blades on a drill bit. The method also includes capturing a plurality of frames of a plurality of blades on a drill bit and identifying a plurality of cutters on each of the blades in the frames. The method also includes identifying a first subset of the cutters that are primary cutters and arranging the primary cutters in a first order, and identifying a second subset of the cutters that are secondary cutters and arranging the secondary cutters in a second order. The method also includes extracting a thumbnail image of each of the cutters from the frames in the first order and/or the second order. The method also includes identifying cracks and/or erosion damage on the cutters based upon the extracted thumbnail image.
A method for processing well log data includes obtaining input data including the well log data. The well log data may include a plurality of datasets. Each dataset of the plurality of datasets includes one or more log curves and is associated with a respective well of one or more wells. The method also includes harmonizing the plurality of datasets using a curated dictionary to produce harmonized datasets. The method further includes reconstructing the one or more log curves of each harmonized dataset of the harmonized datasets to produce reconstructed logs using a supervised machine-learning (ML) model. The method also includes generating normalized datasets based on the harmonized datasets and using log normalization. The method also includes generating an output based on the reconstructed logs and the normalized datasets.
G06F 18/2413 - Classification techniques relating to the classification model, e.g. parametric or non-parametric approaches based on distances to training or reference patterns
6.
DRILL PIPE ALIGNMENT IN ROTATING CONTROL DEVICE MONITORING SYSTEM
A system for determining a misalignment of a drill pipe includes a rotating control device (RCD) including a housing defining a bore through which the drill pipe is configured to extend. The system also includes a monitoring system coupled to and/or in communication with the RCD. The monitoring system includes one or more sensors coupled to and/or positioned within the housing. The one or more sensors include load cells that are configured to measure a force exerted on the housing. The monitoring system is configured to determine the misalignment between the drill pipe and the RCD based upon the force.
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
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 19/24 - Guiding or centralising devices for drilling rods or pipes
E21B 19/086 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods with a fluid-actuated cylinder
E21B 19/09 - Apparatus for feeding the rods or cablesApparatus for increasing or decreasing the pressure on the drilling toolApparatus for counterbalancing the weight of the rods specially adapted for drilling underwater formations from a floating support using heave compensators supporting the drill string
7.
SYSTEMS AND METHODS FOR DOWNHOLE MINERAL LOGGING AND RESERVOIR ZONE QUALITY EVALUATION
A system includes a sampling tube and a sampling system. The sampling tube is configured to be disposed at a depth in a mineral extraction well and is configured to receive brine from the mineral extraction well at the depth. The sampling system is configured to be disposed at the surface of the mineral extraction well and to receive the brine from the sampling tube, determine the depth in the mineral extraction well from which the brine was collected based on a position of the sampling tube and a parameter representative of a flow rate of the brine through the sampling tube, and determine a concentration of one or more elements of interest in the brine.
A method, includes obtaining one or more samples obtained from a wellbore fluid circulated through a wellbore drilled in a geological formation at a downhole location and returned from the geological formation, wherein the one or more samples contain a target element, placing the one or more samples into a measurement device, determining a concentration of the target element in the one or more samples using the measurement device, and evaluating at least one criterion relative to an extraction plan to generate at least one evaluated criterion corresponding to extracting the target element at the location based on the concentration.
An operating planning system may receive survey data for the wellbore. An operating planning system may, using the survey data, calculating deviations from a planned trajectory of the wellbore. An operating planning system may apply a physical model to the deviations to identify forces on a downhole tool. An operating planning system may, based on the deviations and the forces, generating an operational plan to perform the operation.
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 47/022 - Determining slope or direction of the borehole, e.g. using geomagnetism
10.
IDENTIFYING LANDING OF DOWNHOLE EQUIPMENT AT A WELLHEAD
A wellhead landing, locking and sealing detection system may receive an acoustic signal from at least one acoustic sensor located on an outer surface of a wellhead. A wellhead landing, locking and sealing detection system may process the acoustic signal resulting in a processed acoustic signal. Processing the acoustic signal may include normalizing the acoustic signal, smoothing the acoustic signal, and differentiating a background signal from the acoustic signal. A wellhead landing, locking and sealing detection system may select a portion of the processed acoustic signal. A wellhead landing, locking and sealing detection system may identify a reflection characterization, frequency or profile from the portion. A wellhead landing, locking and sealing detection system may, based on the reflection characterization, frequency or profile, identifying a landing, locking and sealing configuration of the equipment with the wellhead.
A tangible and non-transitory machine readable medium including instructions to operate a monitoring tool in a setup mode and a normal operational mode. The monitoring tool includes one or more sensors, a power supply, and a controller coupled to the one or more sensors and the power supply, wherein the controller has a processor, a memory, and instructions stored on the memory and executable by the processor. The setup mode is configured to collect sensor data during a first rotational movement of the monitoring tool about a central axis of a mount, obtain calibration data based on the sensor data, calibrate the monitoring tool based on the calibration data, and identify a true North orientation of the monitoring tool during a second rotational movement of the monitoring tool about the central axis of the mount.
A device may include a body having a rotational axis. A device may include a steering pad, the steering pad being movable radially outward relative to the body at a hinge. A device may include a bore formed in the body, the bore having a bore longitudinal axis that is at least partially radially relative to the rotational axis of the body. A device may include a piston in the bore and movable in the bore to apply a radially outward force to the steering pad.
Techniques and systems for training and deploying a machine learning model. This includes receiving first data, receiving second data, training a machine learning (ML) model of a neural network utilizing training data based upon the first data to generate a first trained ML model, isolating a first set of layers of the neural network from a second set of layers of the neural network, training a portion of the first trained ML model of the second set of layers of the neural network utilizing the second data to generate a fully trained ML model, and deploying the fully trained ML model on a data processing system to interpret received measurements collected in conjunction with a natural resource operation.
H04L 67/12 - Protocols specially adapted for proprietary or special-purpose networking environments, e.g. medical networks, sensor networks, networks in vehicles or remote metering networks
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
E02D 1/02 - Investigation of foundation soil in situ before construction work
A system includes an annular seal that includes an annular seal jacket, such that the annular seal jacket includes an annular base, first and second annular walls coupled to the annular base, and an annular chamber disposed between the first and second annular walls. Additionally, the annular seal includes a first spring disposed in the annular chamber and a second spring disposed in the annular chamber.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 33/129 - PackersPlugs with mechanical slips for hooking into the casing
15.
SYSTEMS AND METHODS FOR NON-CONTACT MEASUREMENT FOR SOLIDS DISCHARGE
A method for analyzing solids discharged from a drilling process is provided. The method includes detecting a velocity and depth of discharged solids. The method determines a detected flow rate of the discharged solids based on the velocity and the depth of the discharged solids. A system for analyzing discharge from a drilling process, is provided. The system includes a centrifuge system for separating fines from a discharge, an imaging system for providing images of the discharge provided by the centrifuge system, and a processor configured to determine a volume of the discharge based on the images of the discharge.
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
E21B 47/002 - Survey of boreholes or wells by visual inspection
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 downhole heating tool for activating a polymeric sand screen includes an outer pipe and an inner pipe disposed within the outer pipe. A reacting media is disposed within the inner pipe, the reacting media is configured to undergo an exothermic chemical reaction. A pressure activated trigger isolates the reacting media from a fluid pressure outside the inner pipe, the pressure activated trigger being activatable by a pressure signal to initiate the exothermic chemical reaction of the reacting media. A sand screen is disposed about the outer pipe. The pressure activated trigger may include a rupture disc or an electrical switch. A one-way flow mechanism may be in communication with an end of the inner pipe. A heat moderation fluid may be disposed in a space defined between the outer pipe and the inner pipe.
A swage element includes a sleeve having a first outer arm, a second outer arm, and an intermediate support disposed between them. The first outer arm and intermediate support define a first channel, and the second outer arm and intermediate support define a second channel. An elastomeric element is disposed in both channels. The elastomeric element includes a first portion in the first channel having an internal surface bonded to the sleeve and an outer surface defining a first groove, and a second portion in the second channel having an internal surface bonded to the sleeve and an outer surface defining a second groove. The intermediate support includes a tapered face configured to direct deformation of the elastomeric element toward a sealing surface under fluid pressure, enabling self-energization.
A method may include receiving input during execution of a field operations framework, where the field operations framework includes components for one or more of planning field operations and controlling field operations, and where the input corresponds to a workflow that includes a series of tasks; responsive to receipt of the input, automatically accessing one or more large language models to generate output based at least in part on a portion of the input; automatically transmitting the output to a task-oriented reasoning component to generate one or more agent instructions; automatically transmitting at least one of the one or more agent instructions to a corresponding agent; and, responsive to the transmitting, automatically issuing at least one rendering instruction for rendering information to a display, where the information facilitates performance of one or more of the tasks of the workflow.
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
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 backpressure relieving system for an open hole high expansion packer includes a first unidirectional sealing element and a second unidirectional sealing element spaced apart from the first unidirectional sealing element. A trapped volume zone is defined between the first unidirectional sealing element and the second unidirectional sealing element. A relief valve is in fluid communication with the trapped volume zone. The relief valve is configured to permit fluid flow from the trapped volume zone in a single direction. A filter is positioned upstream of the relief valve. The filter is configured to prevent debris from entering the relief valve.
The present disclosure relates to systems and methods for using a generative artificial intelligence system to automatically import data from documents in a standard format. The systems and methods use the generative artificial intelligence system to assist with writing a parsing template to use in converting the data from the documents into the standard format.
A method including receiving cutter lab test data associated with cutter types; generating a first model based on the cutter lab test data, wherein the first model is representative of effects to one or more rock types provided by using the cutter types; receiving bit lab test data associated with drill bits; generating a second model based on the first model and the bit lab test data, wherein the second model is representative of additional effects to the one or more rock types provided by the drill bits; receiving drilling log data associated with additional drill bits; simulating drilling dynamics for the drill bits and additional drill bits based on the second model and the drilling log data; receiving borehole data associated with a borehole; and determining a bit design for use in the borehole based on the simulated drilling dynamics and the borehole data.
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
G06F 30/20 - Design optimisation, verification or simulation
A valve seat for use in a gate valve is provided, and the valve seat includes a first seat body, a sealing element, and an expandable member. The first seat body is movable relative to a valve body. The sealing element is disposed between the first seat body and the valve body. The sealing element restricts fluid flow from a bore of the valve body to an area between the first seat body and the valve body to apply a pressure to the first seat body and the valve body to engage the first seat body with a valve member. The expandable member is disposed between the first seat body and the valve body. The expandable member is configured to provide a preload between the first seat body and the valve body to maintain engagement between the first seat body and the valve member.
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 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 27/04 - Construction of housingsUse of materials therefor of sliding valves
A downhole tool includes a base pipe defining a base pipe passageway, a centralizer coupled to the base pipe, a seal coupled to the base pipe, and a two-stage deployment system configured to deploy the centralizer and the seal. The two-stage deployment system includes a centralizer piston disposed about the base pipe and coupled to the base pipe via a first shear mechanism having a first shear limit. The two-stage deployment system includes a seal piston coupled to the centralizer piston via a second shear mechanism having a second shear limit greater than the first shear limit. The base pipe defines a first port through which pressure from the base pipe passageway is configured to activate the centralizer piston. The base pipe defines a second port through which the pressure is configured to activate the seal piston separately from the activation of the centralizer piston.
E21B 23/01 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for anchoring the tools or the like
E21B 21/10 - Valves arrangements in drilling-fluid circulation systems
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
A method may include generating results for one or more layers of a computational framework; combining the results to generate an optimal operating window (OOW) for drilling operations; and controlling equipment to perform one or more of the drilling operations based on the optimal operating window.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
A cutting element may include a polycrystalline diamond (PCD) table including an apexed working surface. A cutting element may include a body including a non-diamond body material bonded to the PCD table, wherein a PCD height of the PCD table is no less than 40% of a cutting element height including the PCD table and body.
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
E21B 10/567 - Button-type inserts with preformed cutting elements mounted on a distinct support, e.g. polycrystalline inserts
E21B 10/52 - Drill bits characterised by wear resisting parts, e.g. diamond inserts the bit being of roller type with chisel- or button-type inserts
B24D 3/10 - Physical features of abrasive bodies, or sheets, e.g. abrasive surfaces of special natureAbrasive bodies or sheets characterised by their constituents the constituent being used as bonding agent and being essentially inorganic metallic for porous or cellular structure, e.g. for use with diamonds as abrasives
B24D 99/00 - Subject matter not provided for in other groups of this subclass
The present disclosure relates to systems and methods for using an application programming interface to connect with a data engine. The application programming interface uses a messaging software development kit that receives a request for the data engine and converts the request into a message in a format compatible with the data engine. The messaging software development kit facilitates communication with the data engine from the application programming interface.
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.
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 19/22 - Handling reeled pipe or rod units, e.g. flexible drilling pipes
A system for creating a tortuous flow path is disclosed. The system includes a production zone, and a man-made impermeable barrier disposed along a fluid flow path to the production zone to create tortuous flow path for a fluid flowing between the injection zone and the production zone.
A geopolymer slurry includes comprising at least one aluminosilicate source including an amorphous aluminosilicate material, an activator, a fluid loss control material including a crosslinked polymer, and an aqueous base fluid. The crosslinked polymer includes a reaction product of one or more monomers including 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. Related geopolymer compositions and methods of cementing a subterranean borehole are also disclosed.
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
30.
FEDERATED LEARNING APPLICATIONS FOR SECURE AND PRIVATE MACHINE LEARNING IN OIL AND GAS INDUSTRY
Techniques for training a global model for use at a host of oilfield application sites based on raw data obtained from the application sites without direct exposure of the data to the global model. The techniques include developing and distributing a global model with a predetermined set of parameter weights. The model is then locally employed at each application site by a local computer which maintains the integrity of the acquired data during performance of the oilfield application. The data is used to update the parameter weights based on real-time circumstances. Thus, the parameter weights may be transmitted to the centralized computer for updating of the global model. Further, the updated global model may continue to direct other applications and the process continued in a beneficial feedback loop manner.
Techniques for simulating carbon dioxide injection into a saline aquifer. The techniques include obtaining geological reference data that is correlated to a saline aquifer formation layer and establishing a set of carbon dioxide injection parameters to be tested. The simulation is computationally practical and efficient by mathematically partitioning the aquifer formation layer into a plurality of discrete partitions based on the geological reference data and utilizing fast analytical solutions to obtain relevant properties of interest within each partition. Thus, estimating carbon dioxide flow characteristics for each discrete partition of the plurality may take place based on the geological reference data and the carbon dioxide injection parameters.
E21B 43/16 - Enhanced recovery methods for obtaining hydrocarbons
E21B 43/30 - Specific pattern of wells, e.g. optimising the spacing of wells
G06Q 10/04 - Forecasting or optimisation specially adapted for administrative or management purposes, e.g. linear programming or "cutting stock problem"
Techniques for simulating carbon dioxide injection into a saline aquifer. The techniques include obtaining geological reference data and establishing carbon dioxide injection parameters. With this data and parameters in mind, a node-based resistance grid may be established that is used to schematically generate flowlines across the saline aquifer. From the flowlines, tessellated partitions may be developed and potentially subdivided into manageable platonic shape portions. Thus, a mathematical manner of estimating flow characteristics for the proposed injection application may be simulated in a fast and reliable manner.
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 43/16 - Enhanced recovery methods for obtaining hydrocarbons
A method including receiving input data, setting one or more static properties based on the input data, providing the one or more static properties to a model of one or more components of an energy system, generating a plurality of performance curves, transmitting the plurality of performance curves for display via a graphical user interface (GUI), receiving, via the GUI, an input indicative of a selection of a mathematical model, engaging the selected mathematical model, generating, using the selected mathematical model, an allocation of energy to the one or more components of the energy system, and transmitting the allocation for display via the GUI. The input data may include one or more fixed data variables, one or more temporal data variables, or any combination thereof. Each performance curve of the plurality of performance curves may also correspond to a respective component of the one or more components.
H02S 50/00 - Monitoring or testing of PV systems, e.g. load balancing or fault identification
H02S 10/10 - PV power plantsCombinations of PV energy systems with other systems for the generation of electric power including a supplementary source of electric power, e.g. hybrid diesel-PV energy systems
H02S 10/20 - Systems characterised by their energy storage means
H02S 40/44 - Means to utilise heat energy, e.g. hybrid systems producing warm water and electricity at the same time
G06F 3/048 - Interaction techniques based on graphical user interfaces [GUI]
A method may include executing a computational framework to render a graphical user interface to a display that includes graphical controls for specification of bit design optimization properties for one or more formation types; executing multi-objective optimization code according to the bit design optimization properties to generate bit design genotypes; executing genotype-to-phenotype code to generate bit design phenotypes from the bit design genotypes; executing one or more simulators to generate simulation results for the bit design phenotypes; executing fitness vector generation code to generate a fitness vector for the simulation results; and executing the multi-objective optimization code using the fitness vector to generate a set of bit design genotypes.
The invention relates to an arrangement of at least one first solid oxide electrochemical system (100) inside a casing (10), the at least one first electrochemical system having a plurality of at least two stacks (111, 121) of single repeat units (SRU), and a fluid collection box (150), characterized in that: - the plurality of at least two stacks is divided into a first subsystem (110) of stacks (111), held against and connected to the upper face of the fluid collection box, and into a second subsystem (120) of stacks (121), held against and connected to the lower face of the fluid collection box; - the fluid collection box (150) is engaged with the two side walls (16) of the casing (10); such that the first electrochemical system (100) is suspended inside the casing (10).
A method and system for designing a well casing for a target site includes receiving an information set for the target site and generating a plurality of well casing designs for the target site. Each well casing design includes a combination of a selected materials, casing sizes, casing grades, casing weights, and lengths for a set of well casing components. The method then generates a set of estimated loads for the well casing at the target site based on historical data. The set of estimated loads including a collapse load, a burst load, a tension load, a compression load, and a triaxial load. Each of the plurality of well casing designs are tested based on the estimated loads and a list of recommended well casing designs that withstood the set of estimated loads and a higher threshold of loads is generated and a recommended well design is output.
The invention relates to a facility (1) for producing hydrocarbon compounds comprising a heating device (2), an electrochemical device (3) and a hydrocarbon compound production device (6) configured to produce hydrocarbon compounds from an internal fluid of the electrochemical device (3) comprising dihydrogen and an inlet fluid comprising carbon dioxide. The facility is also designed to recover at least a portion of the waste heat released by the hydrocarbon compound production device (6) and to transfer it to the heating device (3).
A method for planning a relief wellbore includes identifying a blowout trajectory (142) for a target wellbore (140), determining a plurality of candidate relief trajectories (146) from a plurality of surface locations around the blowout trajectory for a plurality of candidate relief wellbores to intersect the target wellbore at an intersection point. For each surface location, an operational difficulty is predicted for the surface location based at least in part on the plurality of candidate relief trajectories. The method further includes generating a heat map indicating the operational difficulty for the plurality of surface locations, and presenting the heat map via a graphical user interface (GUI) including presenting a normalized heat index overlayed on a geographical presentation of the plurality of surface locations.
A method may include identifying known parameters based on a geological model representative of a subsurface region and identifying uncertain parameters associated with the geological model based on the known parameters and field operations previously performed within the subsurface region. The operations may also include generating a simulated test design to estimate the uncertain parameters based on the known parameters by determining a sensitivity coefficient matrix at different time points for each of one or more simulated measurements associated with estimated uncertain parameters based on the simulated test design and determining a residual uncertainty associated with the estimated uncertain parameters based on the sensitivity coefficient matrix. The method may also include generating an updated simulated test design to estimate the second set of parameters based on the known parameters in response to the residual uncertainty being greater than a threshold.
A gas lift valve includes a valve body defining radial inlets and a seat. A sleeve is slidably coupled to the valve body, including a sleeve body defining a Venturi passageway and a radial seal disposed about the sleeve body opposite the seat. An actuator is coupled to the sleeve to move it relative to the valve body. A check valve is positioned with the seat disposed between the check valve and the sleeve body. The sleeve is movable between an open position and a closed position. In the open position, the sleeve is positioned between the radial inlets and the check valve with the sleeve body against the seat, leaving the radial inlets unobstructed. In the closed position, the radial seal is disposed against the radial inlets to obstruct them.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 34/08 - Valve arrangements for boreholes or wells in wells responsive to flow or pressure of the fluid obtained
F16K 11/16 - Multiple-way valves, e.g. mixing valvesPipe fittings incorporating such valvesArrangement of valves and flow lines specially adapted for mixing fluid with two or more closure members not moving as a unit operated by one actuating member, e.g. a handle which only slides, or only turns, or only swings in one plane
F16K 11/02 - Multiple-way valves, e.g. mixing valvesPipe fittings incorporating such valvesArrangement of valves and flow lines specially adapted for mixing fluid with all movable sealing faces moving as one unit
41.
A VALVE ASSEMBLY FOR SELECTIVELY PERMITTING FLUID FLOW THROUGH SHUNT TUBES
A valve assembly for controlling fluid flow through shunt tubes disposed in a wellbore is provided. The valve assembly includes a tubular body, a valve member, and an actuation system. The tubular body includes a shunt tube port fluidly coupling a shunt tube uphole of the tubular body and a second shunt tube downhole of the tubular body. The valve member includes a valve port and is disposed within a bore intersecting the shunt tube port. The valve member is positionable in a first angular position and a second angular position. In the first angular position, the valve port is aligned with the shunt tube port. In the second angular position, the valve port is misaligned with respect to the shunt tube port. The actuation system is coupled to the valve member and is configured to position the valve member in the first angular position and the second angular position.
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
The present disclosure relates to a shaped charge. The shaped charge includes an explosive component and a shaped charge case surrounding an exterior surface of the explosive component. The shaped charge also includes a liner member coupled to the explosive component. The explosive component and the liner member are configured to form a perforating jet based on detonation of the explosive component. The shaped charge also includes one or more reactive foils coupled to the explosive component and configured to initiate the explosive component.
The present disclosure provides a method for treating a subterranean formation, may include injecting a treatment fluid into the subterranean formation, the treatment fluid including at least one of an inorganic acid or an organic acid, at least one of hydrofluoric acid or hydrofluoric acid precursor, and a precipitate inhibitor, and after injecting the treatment fluid into the subterranean formation, performing at least one of a fracturing treatment or a stimulation treatment. The inorganic acid includes at least one of hydrochloric acid or methanesulfonic acid. The treatment fluid can further include a blend of organic acids including at least one of citric acid, acetic acid, formic acid, or lactic acid. The hydrofluoric acid precursor includes at least one of ammonium bifluoride or ammonium fluoride. The precipitate inhibitor prevents precipitation of calcium fluoride and magnesium fluoride. The treatment fluid can be pumped in a single step without requiring a preflush treatment.
Embodiments presented provide for a method and apparatus for downhole tracer technology. A method for deployment and interpretation of tracers in a geological formation disclosed. The method comprises conveying a downhole testing apparatus to a desired elevation within a wellbore, setting a dual-packer arrangement, defining a position to evaluate next to the wellbore, pumping mud from an interval defined by the dual-packer arrangement, injecting at least one tracer carried by a volume sampling chamber of the downhole testing apparatus into the formation, circulating a fluid other than mud to a bottom of the drill pipe, injecting the fluid other than mud into the interval, and deflating the dual-packer arrangement. In specific embodiments, different tracers may be placed into an injection well and amounts of residual carbon dioxide saturation may be determined.
Aspects of the disclosure provide for sensor placement for gas emission detection using record count. A method for sensor placement includes obtaining wind rose distribution data associated with a site for gas emission detection and generating a plurality of wind realizations from the wind rose distribution data. The method includes generating a plurality of records associated with predicted sensor measurements at each candidate sensor location for each of a plurality of potential gas emission locations at the site and subject to each of the plurality of wind realizations and ranking the candidate sensor location based on a record count. The method includes iteratively selecting for gas emission detection sensor placement a candidate sensor location, from the plurality of candidate sensor locations, having a highest ranking and removing at least the selected candidate sensor location from the plurality of candidate sensor locations.
Systems and methods are described herein for methane leak detection. In an example, a computing device can determine site geometry of a location where a methane leak may occur. Using the site geometry and local wind data, the computing device can determine the location, orientation, and spatial extents of a scan plane. The scan plane can include scanning locations for the drone to scan for methane. The computing device can upload the flight plan to a drone that executes the flight plan, scanning for methane at the designated locations. The computing device can download data from the drone after the flight and calculate the concentration of any methane detected by the scan.
Installation (1) comprising a thermal enclosure (2) housing an electrochemical device (3) of the high-temperature electrolyzer or high-temperature fuel cell type. The installation (1) comprises a dilution device (4) configured to introduce into the enclosure (2) a purge fluid such as ambient air, so as to reduce the risk of explosion associated with hydrogen and oxygen leaks. Corresponding method.
A method to quantity clay content may comprise flowing a rock sample with water, wherein the water is collected, and a capillary electrophoresis analysis or any water analysis method is run on the water. The method further comprises calculating a clay integrated area using constructed water analysis peaks. Lastly, a correlation to quantify the clay content in the rock sample, and another correlation to quantify the clay content in the water sample are formulated.
Aspects of the disclosure relate to a method for understanding the response of any multi-detector device to activated oxygen. The method relies on an expression of a three-dimensional distribution of activated oxygen from fast neutron, and on the expression of three-dimensional gamma ray detection efficiency. A realistic model is derived for the signals measured in the detectors as function of the device-to-oxygen differential velocity.
G01V 3/14 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electron or nuclear magnetic resonance
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 24/08 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
G01N 24/10 - Investigating or analysing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using electron paramagnetic resonance
G01R 33/44 - Arrangements or instruments for measuring magnetic variables involving magnetic resonance using nuclear magnetic resonance [NMR]
Methods, systems, and computer readable storage mediums for managing downhole operations are disclosed. To manage downhole operations, the temperatures of various components of tools used in downhole environments may be taken into account. To preserve the life of the components of the tools, cooling flows may be used to retain temperatures of the components within operating ranges. By retaining the temperatures of the components within the operating ranges, the components may be less likely to become damaged, become impaired, and/or operate in undesired manners.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
E21B 36/00 - Heating, cooling or insulating arrangements for boreholes or wells, e.g. for use in permafrost zones
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
A system may obtain flow gradient survey (FGS) data for a well at a first location in the well. A system may obtain a measured gas-injection rate from a gas-lift orifice valve in the well. A system may calculate a logarithmic ratio factor based on the FGS data and a downhole gas injection pressure at the first orifice. A system may determine a calculated flowing pressure based on the logarithmic ratio factor. A system may adjust the downhole gas injection pressure based on the calculated flowing pressure.
A method for detecting a washout or overpressure event. The method includes receiving data signals from sensors at a wellsite, wherein the data signals include at least one surface originated measurement such as flowrate and a plurality of downhole originated measurements including turbine RPM. After any transient regions or outliers from the received data signals have been removed, a current downhole measurement signal may be compared with at least one previous downhole measurement signal from the same data signal to determine a predicted baseline. A current downhole measurement signal may be reported as suspicious each time it is detected to be lower than a predetermined threshold relative to the predicted baseline. An alarm may then be provided which indicates a washout or overpressure event when a threshold number of suspicious measurement signals have been detected. A wellsite action may then be performed that is based on the activated alarm.
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 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
Method and apparatus for detecting particles in a fluid are described herein. Such methods and apparatus can be used for bulk separation of solids and liquids in a hydrocarbon prospecting setting. In such cases, a solid liquid separation apparatus includes a shaker filtration device; a circulation conduit to circulate a fluid product of the shaker filtration device; a filtration medium disposed in the circulation conduit; and a pressure sensor adjacent to the filtration medium. The pressure sensor is used to monitor pressure adjacent to the filtration medium. An abnormal pressure reading, or plurality of readings, is used to indicate an event of particle leakage needing attention.
A technique for determining cement bond logging analysis for a cased well. The technique is directed at obtaining more in depth information regarding overall cement bond integrity so as to avoid premature remedial intervention based on false indication of compromised cement bonding at the casing and formation interface. This includes incorporating a dipole transmitter at a logging tool that is configured to emit lateral pressure pulses toward the casing in order to obtain dipole waveforms back from at least one predetermined cutoff depth that is beyond that of an ultrasonic wave reach outside of the casing. This may be undertaken in light of information previously obtained from ultrasonic detections indicative of at least some degree of micro-debonding and may be followed by remedial intervention once confirmed that the micro-debonding is exceeded to a point of compromised integrity of the cement bond.
Methods, systems, and computer readable storage mediums for managing testing of a well to facilitate completion of the well is disclosed. The system may include a tool usable to perform testing on the well. The tool may include a circulation assembly, a primary control assembly, and a secondary control assembly. The circulation assembly may be reconfigurable by selectively isolating an annulus of the well from a fluid chamber of the circulation assembly. The primary control assembly may facilitate reconfiguration of the circulation assembly to selectively isolate the annulus, and facilitate flowing of various fluids and gasses to perform the testing. The secondary control assembly may serve as a partial backup for the primary control assembly usable to address undesired conditions in the well when the primary control assembly is unable to reconfigure the circulation assembly independent to address the undesired 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
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
E21B 47/18 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves through the well fluid
E21B 49/10 - Obtaining fluid samples or testing fluids, in boreholes or wells using side-wall fluid samplers or testers
A method includes receiving raw measurements of a well, receiving thickness measurements from a well completion file of the well, receiving computed thickness measurements of the well, clustering the raw measurements into a first plurality of clusters, wherein each cluster of the first plurality of clusters corresponds to a particular range of depths, obtaining a corrected phase thickness using the first plurality of clusters, the signals, and the computed thickness measurements, clustering the thickness measurements from the well completion file into a second plurality of clusters, obtaining a corrected well thickness using the second plurality of clusters, the well completion file, and the computed thickness measurements, and identifying corrections in the computed thicknesses from corrected raw measurement thickness and corrected well completion thickness based on differences between each of the corrected raw measurement thickness, the corrected well completion thickness, and the computed thickness measurements.
Method and apparatus for drilling wells and processing drilling fluids are described herein. A method of processing a drilling fluid includes reducing pH of the drilling fluid to convert dissolved sulfides to hydrogen sulfide to form a low pH fluid; removing hydrogen sulfide from the low pH drilling fluid using a mechanical treatment to form a reduced sulfide fluid; and raising the pH of the reduced sulfide fluid to form a reduced sulfide drilling fluid precursor. The drilling fluid subjected to such treatment can be reused with minimal use of fresh water.
Embodiments presented provide for a gasket composition. Embodiments provide a composition that provides superior material features that allows for limitation of elasticity reduction damage for installations over time. Embodiments presented provide a gasket composition comprising at least one layer of one or more polymer compounds with a specified tensile strength, hardness, and a minimum thermal expansion coefficient.
Techniques and systems for determining eccentering in concentric pipes. A device includes a data acquisition tool to generate measurements related to eccentering characteristics of a first pipe concentrically surrounding the tool and second eccentering characteristics of a second pipe concentrically surrounding the tool and the first pipe. The tool includes a transmitter to generate at least one first time-varying magnetic field at a first frequency and at least one second time-varying magnetic field at a second frequency, a first receiver disposed at a first distance from the transmitter along the tool to measure a first change in voltage in the first pipe in response to the at least one first time-varying magnetic field, and a second receiver disposed at a second distance from the transmitter along the tool to measure a second change in voltage in the second pipe in response to the at least one second time-varying magnetic field.
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
G01V 3/28 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with magnetic or electric fields produced or modified either by the surrounding earth formation or by the detecting device using induction coils
60.
SYSTEMS AND METHODS FOR CARBON DIOXIDE CAPTURE VIA DESUBLIMATION AND SUBLIMATION STAGES IN A HEAT EXCHANGER
An inductive communication link for use in a bottom hole assembly includes an outer antenna assembly including an outer antenna deployed and sealed in an outer antenna housing, an inner antenna assembly including an inner antenna deployed and sealed in a pin end of an inner antenna housing, wherein the open axial end of the outer antenna housing is configured to receive the pin end of the inner antenna housing such that the inner antenna is inductively linked with the outer antenna.
E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
A downhole tool includes first and second electrical conductors and a relay deployed in and rotationally coupled to a first housing. The first and second electrical conductors are electrically connected to the relay. A solenoid is rotationally coupled with a second housing which is rotationally independent from the first housing. The solenoid is configured to actuate the relay and thereby electrically connect or disconnect the first electrical conductor to or from the second electrical conductor.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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 for automatically predicting subsurface formation tops based upon well log data using a convolutional neural network (CNN) includes receiving first well log data corresponding to a plurality of first wells. The first well log data includes first marker tops in the first wells. Labels on the first sequences indicate a presence or absence of first formation tops within first sequences in the first well log data. The method also includes training a convolutional neural network (CNN) using the cleansed well log data. The method also includes receiving second well log data corresponding to a plurality of second wells. The method also includes identifying second formation tops in the second well log data using the trained CNN. Identifying the second formation tops includes predicting a probability that one or more second marker tops is in each of a plurality of second sequences in the second well log data.
Acid-resistant alkali-activated materials are presented. A composition is presented herein that includes a polymerization product of an alkali-reactive aluminum-silicon-oxygen material and an alkaline solution; and from about 0.1 weight percent to about 5 weight percent of a nanoparticle material having particle size less than about 500 nm disposed in spaces of the composition, wherein the composition is acid resistant. A method herein includes preparing an alkali-activated precursor using an alkali-reactive aluminum-silicon-oxygen material, an alkaline material, and a nanoparticle material having particle size of about 500 nm or less and being present in the precursor mixture in a concentration of about 0.1 percent to about 5 percent by weight of the precursor mixture; deploying the precursor to a target location; and allowing the precursor to set to obtain an acid-resistant cementitious material.
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 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
65.
ACOUSTIC ANOMALY DETECTION OF OIL AND GAS PROCESSING EQUIPMENT USING SPECTROGRAM-BASED MACHINE LEARNING
A method for detecting acoustic anomalies in oil and gas processing equipment includes receiving first audio data that is generated by the oil and gas processing equipment. The method also includes segmenting the first audio data into a plurality of time frames. The method also includes extracting a spectrum from the time frames. The method also includes generating a spectrogram based upon the spectrum. The method also includes training a machine learning (ML) audio model based upon the spectrogram. The method also includes receiving second audio data that is generated by the oil and gas processing equipment or different oil and gas processing equipment. The method also includes determining an output using the trained ML audio model based upon the second audio data.
G10L 25/51 - Speech or voice analysis techniques not restricted to a single one of groups specially adapted for particular use for comparison or discrimination
G10L 25/18 - Speech or voice analysis techniques not restricted to a single one of groups characterised by the type of extracted parameters the extracted parameters being spectral information of each sub-band
G10L 25/30 - Speech or voice analysis techniques not restricted to a single one of groups characterised by the analysis technique using neural networks
A technique facilitates reliable operation of a blowout preventer (BOP) system in a wide range of challenging environments. The BOP system is an electrical system comprising electrically powered components. The electrically powered components are connected with a primary energy storage device which provides electric power for operating those components. Additionally, a secondary energy storage device may be connected to the primary energy storage device in a manner so as to maintain a desired level of charge on the primary energy storage device. The secondary energy storage device has a longer lifespan and a lower discharge rate compared to the primary energy storage device. By way of example, the secondary energy storage device may be in the form of a secondary battery which is nuclear powered.
An inductive coupler connection for an electrical downhole tool, which can be made up offline. A male inductive coupler can be coupled to a permanent downhole cable, and a female inductive coupler can be coupled to the electrical downhole tool. The couplers are pre-installed on the cable and tool offline, thereby improving deployment efficiency.
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 performing waveform labelling for subsurface monitoring of carbon capture, utilization, and storage (CCUS) monitoring is disclosed. The method includes: receiving a baseline model of a subsurface of a carbon monitoring site; identifying one or more zones within the baseline model that are candidates for containing carbon dioxide (CO2); assigning different labels to the one or more zones; generating masks for each of the one or more zones using the assigned labels; receiving a baseline survey and/or a monitoring survey; and applying the masks to the baseline survey and/or the monitoring survey to produce a masked baseline survey and/or a masked monitoring survey.
A method for performing reservoir management at a wellsite is disclosed. The method includes receiving data from a plurality of sources and generating a reservoir model from the received data. Generating the reservoir model includes initializing a plurality of particles based upon the received data; evaluating an objective function at a position for each of the particles; and updating the position for each of the particles. The method further includes displaying the generated reservoir model on a display.
E21B 47/003 - Determining well or borehole volumes
E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
A method for coloring full waveform modelling may include running first and second modelling experiments that represent a first and a second seismic wavefield, respectively, where the first and second seismic wavefields differ from one another. The method may also include identifying a wavefield event at a particular time step in the first modelling experiment and/or a region of interest in the first modelling experiment, creating a model attribute that discriminates the wavefield event and/or the region of interest from a remainder of a model in the first modelling experiment and multiplying the model attribute with at least a portion of the second seismic wavefield. The method may also include dividing the second seismic wavefield by the first seismic wavefield to produce an estimated wavefield attribute and separating the first seismic wavefield using the estimated wavefield attribute to produce a separated first seismic wavefield.
G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
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 determining an activity state of a tubular assembly in a wellbore includes receiving input data. The input data includes sensor data captured by a sensor at a drilling floor above the wellbore. The input data also includes contextual information including (1) a length and a type of the tubular assembly and (2) a well activity that is being performed using the tubular assembly. The method also includes determining a drill state based upon the input data. The method also includes determining the activity state of the tubular assembly based upon the well activity and the drill state.
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 present disclosure provides an optical fiber bundle including a core element having a first hardness, a first optical fiber helically stranded about the core element, the first optical fiber having a second hardness less than the first hardness, and a second optical fiber helically stranded about the core element. The core element is configured to deform into a compressed state in response to axial or compressive force acting on the optical fiber bundle to provide strain relief to the first and second optical fibers. The core element may include a metallic wire having a soft polymer coating, twisted yarn, yarn laid parallel around a wire with polymer coating, or a monofilament of polymeric material. The optical fiber bundle may further include filler material surrounding the optical fibers and filling interstitial spaces.
G02B 6/44 - Mechanical structures for providing tensile strength and external protection for fibres, e.g. optical transmission cables
G02B 6/04 - Light guidesStructural details of arrangements comprising light guides and other optical elements, e.g. couplings formed by bundles of fibres
A method for controlling parameters for drilling equipment includes receiving input data related to drilling equipment. The method also includes creating a plurality of scenarios based upon the input data. Each scenario includes a plurality of first parameters. Creating the scenarios includes selecting first values for each of the first parameters. The method also includes selecting one or more of the scenarios and one or more second parameters. The method also includes simulating the one or more selected scenarios to determine second values for the one or more selected second parameters.
The invention relates in particular to a facility for producing dihydrogen, the facility comprising an electrochemical device (1) and a fluid network that comprises at least one inlet pipe (3) configured to convey a fluid inlet flow to the electrochemical device (1). The inlet pipe (3) is provided with a first heat exchanger (10), the first heat exchanger (10) belonging to a first heating stage (E1) for heating the inlet flow using the heat of an outgoing flow (4, 9) from the electrochemical device (1) in order to increase the heat of the fluid inlet flow through a recirculation branch, and an electric gas heater (5) positioned downstream of the first exchanger (10). The inlet pipe (3) is also provided with a second heat exchanger (20) belonging to a second heating stage (E2), the two heating stages (E1, E2) being positioned one after the other on the inlet pipe (3).
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
C25B 15/021 - Process control or regulation of heating or cooling
H01M 8/04007 - Auxiliary arrangements, e.g. for control of pressure or for circulation of fluids related to heat exchange
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
77.
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
82.
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 (646), 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 (648). 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 (650). A system may identify at least one drilling dysfunction based on correlated accelerometer data and engagement measurements (652). A system may change at least one wellbore parameter based on the correlated accelerometer data and engagement measurements (654).
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
87.
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.
G01N 11/00 - Investigating flow properties of materials, e.g. viscosity or plasticityAnalysing materials by determining flow properties
G01N 33/00 - Investigating or analysing materials by specific methods not covered by groups
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
92.
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
93.
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
94.
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
95.
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
97.
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.
