The disclosure relates to a system for monitoring methane emissions at industrial facilities. The system includes a network of methane emission detectors at different locations within at least one industrial facility; a gateway device operably coupled to the network of methane emission detectors; and a cloud computing environment operably coupled to the gateway device; wherein the network of methane emission detectors is configured to perform time-series measurements at different locations within the at least one industrial facility and wirelessly communicate time-series sensor data representing such measurements to the gateway device; wherein the gateway device is configured to process the time-series sensor data to derive time-series operational data and communicate the time-series operational data to the cloud computing environment; and wherein the cloud computing environment is configured to receive and process the time-series operational data to detect and characterize methane emission at the at least one industrial facility.
G05B 19/418 - Total factory control, i.e. centrally controlling a plurality of machines, e.g. direct or distributed numerical control [DNC], flexible manufacturing systems [FMS], integrated manufacturing systems [IMS] or computer integrated manufacturing [CIM]
G01N 33/00 - Investigating or analysing materials by specific methods not covered by groups
A method can include receiving input for a multiwell pad; selecting, based at least in part on a portion of the input, a template for the multiwell pad; generating, based at least in part on the template, well trajectories for the multiwell pad, where each of the well trajectories extends from a surface location of the multiwell pad to one or more reservoir target locations and where each of the well trajectories includes at least one curve generated using one or more dogleg severity values and one or more geometric control points that are not required to lie on one or more of the well trajectories; and outputting specifications for the generated trajectories of the multiwell pad.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
3.
DIGITAL FRAMEWORK FOR DESIGN AND SELECTION OF PARAFFIN INHIBITORS
A method of selecting paraffin inhibitors for a target crude oil includes inputting one of more known properties of a target crude oil into a machine learning model and extrapolating unknown properties of a historical data set using a machine learning model. The machine learning model is trained on the historical data set that includes one or more properties of a plurality of crude oils, one or more properties of a plurality of paraffin inhibitors, and one or more paraffin inhibiting efficiencies of the paraffin inhibitors with the plurality of crude oils. Paraffin inhibiting efficiency is predicted based on the historical data set and extrapolated unknown properties for the plurality of paraffin inhibitors that may be used with the target crude oil. One or more of a list of crude oils having one or more properties within a numerical tolerance of the properties of the target crude oil, a list of paraffin inhibitors for use with the target crude oil, and a list of paraffin inhibitor properties are output.
Alkali activated precursor compositions are presented that are useful for cementing a subterranean well, among other uses. The precursor compositions are dry mixtures that have an aluminosilicate source and an activator consisting of a metal carbonate, metal silicate, or combination thereof. A precursor is formed by adding water to the dry precursor compositions. Such precursors have suitable characteristics for use in cementing applications that use pumpable mixtures.
E21B 33/14 - Methods or devices for cementing, for plugging holes, crevices or the like for cementing casings into boreholes
C09K 8/46 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement
C09K 8/467 - Compositions for cementing, e.g. for cementing casings into boreholesCompositions for plugging, e.g. for killing wells containing inorganic binders, e.g. Portland cement containing additives for specific purposes
C04B 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
Certain aspects of the disclosure are directed to methods for obtaining a drilling sequence. The method may include accessing data for actual and planned well trajectories; identifying potential collisions between the actual and planned well trajectories; adjusting the planned well trajectories to mitigate the identified potential collisions; and generating a drilling schedule based on the adjusted planned well trajectories.
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
6.
ML DRIVEN AUTOMATED SCREENING AND RANKING OF POTENTIAL CCS SITES
Disclosed are methods, systems, and computer programs that determine an optimal location for fluid storage operations at a first site (e.g., a carbon capture and storage (CCS) site). The methods include: determining first data for the first site; generating a trained first ML model using the first data; generating preliminary location data associated with the first site using the trained first model; receiving second data associated with the first site; generating a trained second ML model based on the second data; and determining optimal locations at the first site where fluid can be stored by applying to the trained second ML model, the preliminary location data associated with the first site.
Systems and methods presented herein relate to techniques for modeling bridging and fluid diversion and generating a bridging volume output and/or fluid diversion output that indicates a bridging occurrence and/or operations to remedy the bridging. For example, a method includes utilizing a physics based empirical model to predict fluid diversion away from a constriction of a fluid diverter system based on an injection rate, concentration of diverter material, particulate type ratios of particulate types in the fluid diverter system, carrier fluid rheology, or a combination thereof. The method also includes generating an output based on the predicted fluid diversion.
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 identifying a prospect in a subsurface formation includes receiving first data corresponding to one or more first subsurface formations. The method also includes training a machine learning (ML) model using the first data to produce a trained ML model. The method also includes receiving second data corresponding to one or more second subsurface formations. The method also includes identifying second prospects in the one or more second subsurface formations. The second prospects are identified using the trained ML model based upon the second data. The method also includes determining a chance of success in each of the second prospects using the trained ML model based upon the second data.
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
Certain aspects of the present disclosure provide quantitative brine analysis techniques for mineral extraction. A method includes obtaining parameters of a sample brine extracted from the aqueous source; determining a brine pretreatment score based on one or more of the parameters of the sample brine; determining a brine extraction score based on one or more of the parameters of the sample brine; determining a brine post-extraction score based on one or more of the parameters of the sample brine; determining a brine total score based on the brine pretreatment score, the brine extraction score, and the brine post-extraction score; and outputting a visualization of at least one of: the brine pretreatment score, the brine extraction score, the brine post-extraction score, or the brine total score to a display.
Systems and methods presented herein relate to real-time analysis of production chemicals at wellsites utilizing capillary electrophoresis (CE) analysis of produced water in-situ and in substantially real-time to determine the effectiveness and efficiency of production chemicals injected into wells. For example. systems and methods presented herein include CE equipment configured to receive sample fluids from production fluids extracted from various locations of wellsites, and to perform CE analysis to generate data relating to one or more fluid properties of the sample fluids. The systems and methods presented herein also include an analysis and control system configured to detect and quantify individual components of production chemicals injected into wells of the wellsites based at least in part on the data relating to the one or more fluid properties of the sample fluids.
Systems and methods of the present disclosure are configured to enable human annotators to quickly, and potentially in groups, annotate thousands of data points of content, so that each data point of content gets a value with respect to some attribute, so that data points of content showing more of the attribute have higher values than those showing less of the attribute. For example, a method includes presenting two content items of a plurality of content items via a user interface of a web-based application; receiving, via the user interface of a web-based application, an annotation relating to an indication of which of the two content items are associated with a criterion; and updating a score relating to the criterion for each of the plurality of content items based at last in part on the annotation.
Certain aspects of the present disclosure provide brine pre-treatment techniques for direct extraction. A method includes of recovering an element of interest from an aqueous source includes measuring one or more properties of a sample brine extracted from the aqueous source; comparing the measurements of the one or more properties of the sample brine to one or more specified thresholds or ranges; selecting one or more brine pre-treatment stages, of a plurality of configured brine pre-treatment stages, based on the comparison of the one or more properties of the sample brine to the one or more specified thresholds or ranges; and performing the selected one or more brine pre-treatment stages on a process brine extracted from the aqueous source.
C22B 3/24 - Treatment or purification of solutions, e.g. obtained by leaching by physical processes, e.g. by filtration, by magnetic means by adsorption on solid substances, e.g. by extraction with solid resins
A method for implementing enhanced oil recovery includes receiving a model of a subterranean volume of at least a portion of an oilfield and measurements collected for the subterranean volume, determining a model confidence index based at least in part on the model and the measurements, selecting one or more physical parameters for candidate pilot tests based at least in part on the model, the measurements, and the model confidence index, designing pilot tests for the individual candidate pilot tests based at least in part on one or more pilot test objectives, the model, and the model confidence index, selecting one or more pilot tests from among the designed pilot tests, and generating a pilot test implementation plan for the selected one or more pilot tests.
A device may include a bit body with a rotational axis in a longitudinal direction. A device may include at least one blade coupled to the bit body with an outward surface. A device may include a rolling cutting element positioned on the outward surface. A device may include a fixed cutting element positioned with a fixed cutting profile at least partially rotationally overlapping with a rolling cutting profile of the rolling cutting element.
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
A method includes receiving first input values for a first parameter of a physical system, calculating first modeled values for a second parameter using a model that represents the physical system, based on the first input values, receiving measured values for the second parameter, training a machine learning model to adjust modeled values generated by the model based on a difference between the first modeled values and the measured values, receiving second input values for the first parameter, calculating second modeled values for the second parameter using the model, generating adjusted values for the second parameter by adjusting the second modeled values using the trained machine learning model, and visualizing the adjusted values for the second parameter as representing operation of the physical system.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
A method for determining insights about a drilling operation is disclosed. The method also includes generating a prediction for drilling a potential well in a formation in a subsurface based upon the first data and the second data. The method also includes generating a recommendation for drilling the potential well based upon the prediction. The recommendation includes surface coordinates for the potential well, a trajectory of the potential well, an azimuth of the potential well, a well design profile of the potential well, a drilling rig used to drill the potential well, a mud type pumped into the potential well, a bottom hole assembly (BHA) used to drill the potential well, a drill bit used to drill the potential well, or a weight on the drill bit.
Embodiments presented provide for a method for optimizing coiled tubing operations. In embodiments, a pre-job sensitivity analysis is coupled with real-time field measurements to arrive at a decision-making process to enhance the decision making.
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
E21B 43/267 - Methods for stimulating production by forming crevices or fractures reinforcing fractures by propping
Embodiments presented provide for fracture geometry control of hydraulically created fractures in geological stratum. In embodiments, a stimulation well allows for activation of a geological stratum to be fractured, while monitoring activities are conducted by a monitoring well. Data from the monitoring well may be used in creating fracture geometry control of the stimulation well.
A method of selecting paraffin inhibitors for a target crude oil includes inputting one of more known properties of a target crude oil into a machine learning model and extrapolating unknown properties of a historical data set using a machine learning model. The machine learning model is trained on the historical data set that includes one or more properties of a plurality of crude oils, one or more properties of a plurality of paraffin inhibitors, and one or more paraffin inhibiting efficiencies of the paraffin inhibitors with the plurality of crude oils. Paraffin inhibiting efficiency is predicted based on the historical data set and extrapolated unknown properties for the plurality of paraffin inhibitors that may be used with the target crude oil. One or more of a list of crude oils having one or more properties within a numerical tolerance of the properties of the target crude oil, a list of paraffin inhibitors for use with the target crude oil, and a list of paraffin inhibitor properties are output.
E21B 37/06 - Methods or apparatus for cleaning boreholes or wells using chemical means for preventing or limiting the deposition of paraffins or like substances
C09K 8/524 - Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning organic depositions, e.g. paraffins or asphaltenes
20.
MACHINE LEARNING DRIVEN HIGH RESOLUTION SEQUENCE STRATIGRAPHY
Disclosed are methods, systems, and computer programs that determine stratigraphic marker data for energy development operations at a resource site. According to one embodiment, the methods include generating a stratigraphic model for the resource site. The stratigraphic model, for example, comprises a machine learning model having one or more parameters. The methods also include configuring the stratigraphic model using training data following which the trained stratigraphic model is used to generate, based on data captured at the resource site, stratigraphic marker data or geological facies data for the resource site. The stratigraphic marker data or geological facies data comprises geological sequence boundary data indicating uniform or non-uniform sediment deposition information or geological layering information associated with the resource site.
A system includes a first rotary steerable tool configured to control a first drilling bit to drill a first well having a first well path. The first rotary steerable tool includes a first direction and inclination component that includes a first set of sensors configured to detect a static magnetic field and a signal source configured to generate a source signal. The system also includes a second rotary steerable tool configured to control a second drilling bit to simultaneously drill a second well having a second well path that tracks the first well path. The second rotary steerable tool includes a second direction and inclination component that includes a second set of sensors configured to detect the source signal.
A technique facilitates deployment of open hole gravel packing equipment and sand control equipment downhole in a single trip. According to an embodiment, the technique utilizes a pipe string, e.g. a workstring or a drill string, for use in an open hole gravel packing operation. The pipe string is equipped with a sand control system having at least one filtration medium, Additionally, the pipe string comprises a valve and a valve actuation device. The valve actuation device is capable of being remotely activated in a manner allowing setting of one or more packers downhole without blocking subsequent flow through the pipe string.
A drilling fluid management system may measure drilling parameters for a downhole drilling system, the drilling parameters including standpipe pressure. A drilling fluid management system may determine, based on the drilling parameters, a mechanical specific energy (MSE). A drilling fluid management system may apply a changepoint model to the MSE and the standpipe pressure to identify a plurality of MSE segments and a plurality of pressure segments. A drilling fluid management system may identify an expected MSE and an expected pressure. A drilling fluid management system may identify an MSE segment having the segment MSE that differs from the expected MSE by an MSE threshold, and a pressure segment having the segment pressure that differs from the expected pressure by a pressure threshold. A drilling fluid management system may identify a lost-circulation period based on an overlap of the MSE segment and the pressure segment.
E21B 21/00 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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
24.
IMPLICIT STRUCTURAL MODELING USING TREE DATA STRUCTURES
A method includes receiving data representing a subsurface volume, the data including data points representing one or more physical properties of the subsurface volume, generating a tree data structure representing the subsurface volume, including partitioning a digital representation of the subsurface volume into mesh elements based at least in part on locations of the data points, storing a location of the mesh elements in the tree data structure, and assigning coefficients to the mesh elements, the coefficients representing one or more physical properties of the subsurface volume represented by the individual mesh elements. The method also includes determining an implicit function representing the one or more physical properties of the subsurface volume based at least in part on the assigned coefficients, the implicit function being continuous across a domain, and visualizing at least a portion of the subsurface volume based at least in part on the implicit function.
A digital twin generator may receive a model for the physical asset, the model including one or more bound parameters and one or more static parameters associated with the model. A digital twin generator may bind the one or more bound parameters to historical sensor data from a sensor at the physical asset. A digital twin generator may receive a physical measurement from the sensor at the physical asset, the physical measurement including an update to the historical sensor data. A digital twin generator may generate an updated model including the one or more updated bound parameters and the one or more static parameters.
A method for suppressing noise in seismic data includes receiving input seismic data. The method also includes extracting attributes from the input seismic data. The attributes are used to characterize coherent noise in the seismic data. The method also includes identifying noise suppression parameters based upon the attributes. The method also includes applying the noise suppression parameters to the input seismic data to produce output seismic data.
G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
E21B 47/14 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling using acoustic waves
27.
METHOD TO DEVELOP COMPUTER AIDED ENGINEERING MODELS IN HYDROCARBON RECOVERY PROJECTS AND INDUSTRY
Embodiments presented provide for a system that provides calculation for components used in hydrocarbon recovery projects. Arrays of size ranges for components are provided for selection to a designer based on loading conditions expected.
A cleaning cutting element includes an ultrahard layer joined to a substrate. The substrate includes a substrate bore formed at least partially therethrough. The substrate includes a plurality of conduits that extend from the substrate bore at a junction. The conduits exit the substrate at an exit opening in the circumferential wall to direct drilling fluid to a feature of the bit to which the cleaning cutting element is secured.
A method for validating a well test includes receiving historical well test data. The historical well test data includes one or more accepted flags and one or more rejected flags. The method also includes training a machine-learning (ML) model based upon the historical well test data to produce a trained ML model. The method also includes receiving new well test data. The new well test data does not include the one or more accepted flags and the one or more rejected flags. The method also includes determining whether the new well test data meets or exceeds a predetermined validation threshold using the trained ML model.
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
Systems and methods presented herein utilize text mining, Optical Character Recognition (OCR), Natural Language Processing (NLP), and Named Entity Recognition (NER) to extract entity relations for spatial exploration and production (E&P) objects and document categories from unstructured document content autonomously. Language models may be utilized and the results between them may be compared. The extracted information may then be linked to a structured database that contains geolocations.
G06F 16/387 - Retrieval characterised by using metadata, e.g. metadata not derived from the content or metadata generated manually using geographical or spatial information, e.g. location
POLYMER-BASED ADDITIVES FOR SHALE STABILIZATIONS, WELLBORE FLUID COMPOSITIONS COMPRISING SAID ADDITIVES, AND METHODS OF PRODUCING SAID COMPOSITIONS AND IMPROVING SHALE STABILIZATIONS USING SAID COMPOSITIONS
Polymer-based additives improve shale stabilizations by being incorporated into wellbore fluid compositions for one or more wellbore operations or applications. Methods of producing said compositions and using said compositions to stabilize shale associated with wellbores disposed within subterranean formations are also provided. Wellbore fluid compositions comprising aqueous base fluids and the polymer-based additives and methods of introducing or circulating said compositions into the wellbores for stabilizing shales associated the wellbores are further provided.
23030 hydrocarbon radical bonded to one of the nitrogen atoms of the heterocyclic diamine. Relative methods of operating a wellbore and breaker fluid compositions are also disclosed.
Embodiments presented provide for a method for calculating emissions for hydrocarbon recovery operations. In embodiments, databases for equipment and activities are accessed to estimate equivalent greenhouse gas emissions for anticipated wellbore activities.
A method for deploying a pump in a well includes attaching a well closure device above a surface control valve, wherein the surface control valve is connected to close a well tubing extending from the well control valve to a predetermined depth in the well. An annular seal and downhole control valve are moved to a selected pump setting depth in the well tubing. The downhole control valve is operable to close the well tubing to fluid flow. The pump is extended into the well tubing at the end of an electrical cable through the well closure device and the well tubing until the pump engages the downhole control valve or the annular seal. The electrical cable is terminated at its surface end with a well penetrator such that the well penetrator seats in the well closure device.
A fiber optic thread assembly configured with a cumulative gap for mechanical responsiveness and protection from micro-bend damage. The assembly may be incorporated into a wireline or slickline cable for obtaining fiber optic readings of enhanced accuracy during an application in a well. The gap is uniquely tailored to allow for a natural reduction during deployment of the cable into the well, thereby providing the enhanced accuracy. However, the gap is also sufficient to help avoid micro-bend damage from the resulting mechanical responsiveness, which is attained upon deployment of the cable into the well.
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
G01B 11/16 - Measuring arrangements characterised by the use of optical techniques for measuring the deformation in a solid, e.g. optical strain gauge
36.
COLLABORATIVE GENERATION OF CUTTINGS LOGS VIA ARTIFICIAL INTELLIGENCE
A method for generating a depth log of cuttings obtained during a subterranean drilling operation includes acquiring images of the cuttings and labeling the images with a lagged depth at a rig site; generating a clustering of lithology types in the acquired images at a rig the site; transferring the images and the clustering of lithology types from the rig site to an offsite location; evaluating the images and the clustering of lithology types to label each of the lithology types at the offsite location; and generating a description and/or depth log of the labeled lithology types at the offsite location.
G06V 10/26 - Segmentation of patterns in the image fieldCutting or merging of image elements to establish the pattern region, e.g. clustering-based techniquesDetection of occlusion
G06V 10/762 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using clustering, e.g. of similar faces in social networks
G06V 20/70 - Labelling scene content, e.g. deriving syntactic or semantic representations
H04N 7/18 - Closed-circuit television [CCTV] systems, i.e. systems in which the video signal is not broadcast
37.
POLYMER-BASED ADDITIVES FOR SHALE STABILIZATIONS, WELLBORE FLUID COMPOSITIONS COMPRISING SAID ADDITIVES, AND METHODS OF PRODUCING SAID COMPOSITIONS AND IMPROVING SHALE STABILIZATIONS USING SAID COMPOSITIONS
Polymer-based additives improve shale stabilizations by being incorporated into wellbore fluid compositions for one or more wellbore operations or applications. Methods of producing said compositions and using said compositions to stabilize shale associated with wellbores disposed within subterranean formations are also provided. Wellbore fluid compositions comprising aqueous base fluids and the polymer-based additives and methods of introducing or circulating said compositions into the wellbores for stabilizing shales associated the wellbores are further provided.
Methods of stimulating a hydrocarbon reservoir having carbonate components are described herein. An acid treatment material is developed by defining a diversion parameter as a ratio of volume of diversion material to be used for treatment of the reservoir to volume of fractures to be developed during acid treatment of the reservoir, defining a relationship between the diversion parameter and a diversion result, selecting a value of the diversion parameter based on the relationship, determining an amount of diversion material based on the selected value of the diversion parameter, and adding the amount of the diversion material to an acid treatment material. The reservoir is then subjected to acid treatment using the acid treatment material.
A drilling fluid management system may measure drilling parameters for a downhole drilling system, the drilling parameters including standpipe pressure. A drilling fluid management system may determine, based on the drilling parameters, a mechanical specific energy (MSE). A drilling fluid management system may apply a changepoint model to the MSE and the standpipe pressure to identify a plurality of MSE segments and a plurality of pressure segments. A drilling fluid management system may identify an expected MSE and an expected pressure. A drilling fluid management system may identify an MSE segment having the segment MSE that differs from the expected MSE by an MSE threshold, and a pressure segment having the segment pressure that differs from the expected pressure by a pressure threshold. A drilling fluid management system may identify a lost-circulation period based on an overlap of the MSE segment and the pressure segment.
E21B 21/08 - Controlling or monitoring pressure or flow of drilling fluid, e.g. automatic filling of boreholes, automatic control of bottom pressure
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
Embodiments presented provide for an automated method for data input for the hydrocarbon recovery industry. In certain embodiments, data from steps before completion of a wellbore is retained and input into completion software, alleviating the need for manual data retention.
A subsurface hydraulic energy storage system includes a reservoir configured to store a downhole fluid, a turbine coupled to a generator, and an electrical submersible pump (ESP) installed at a target depth in a wellbore in a geological formation. Geothermal heat from the downhole fluid is configured to drive the turbine and the generator, and the generator is electrically connected to an electrical network. The ESP is electrically connected to a power control system electrically connected to the electrical network. The ESP is in fluid communication with the reservoir, and the ESP is configured in an active mode to utilize electrical power from the electrical network to pump the downhole fluid having the geothermal heat from the geological formation to the reservoir.
A method for deploying a pump in a well includes attaching a well closure device above a surface control valve, wherein the surface control valve is connected to close a well tubing extending from the well control valve to a predetermined depth in the well. An annular seal and downhole control valve are moved to a selected pump setting depth in the well tubing. The downhole control valve is operable to close the well tubing to fluid flow. The pump is extended into the well tubing at the end of an electrical cable through the well closure device and the well tubing until the pump engages the downhole control valve or the annular seal. The electrical cable is terminated at its surface end with a well penetrator such that the well penetrator seats in the well closure device.
A method of preventing a collision of a subject wellbore in a downhole environment includes receiving offset wellbore data corresponding with one or more offset wellbores and identifying, based on the offset wellbore data, one or more no-go zones for each of the one or more offset wellbores. The method further includes determining a plurality of safe points corresponding with a potential intersection of the subject wellbore with the one or more no-go zones and, defining an escape zone within the plurality of safe points. The method further includes determining a trajectory for the subject wellbore within the escape zone.
A cleaning cutting element includes an ultrahard layer joined to a substrate. The substrate includes a substrate bore formed at least partially therethrough. The substrate includes a plurality of conduits that extend from the substrate bore at a junction. The conduits exit the substrate at an exit opening in the circumferential wall to direct drilling fluid to a feature of the bit to which the cleaning cutting element is secured.
E21B 10/61 - Drill bits characterised by conduits or nozzles for drilling fluids characterised by nozzle structure
B23K 1/00 - Soldering, e.g. brazing, or unsoldering
B23K 101/00 - Articles made by soldering, welding or cutting
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 10/60 - Drill bits characterised by conduits or nozzles for drilling fluids
A motor lead wire for electric submersible pumps is provided. The lead wire includes solid insulation extruded about a solid copper conductor. The insulation can include a semicrystalline thermoplastic.
H01B 3/42 - Insulators or insulating bodies characterised by the insulating materials; Selection of materials for their insulating or dielectric properties mainly consisting of organic substances waxes polyesters, polyethers, polyacetal
H01B 1/02 - Conductors or conductive bodies characterised by the conductive materialsSelection of materials as conductors mainly consisting of metals or alloys
H02K 3/30 - Windings characterised by the insulating material
H02K 3/44 - Protection against moisture or chemical attackWindings specially adapted for operation in liquid or gas
A method may include receiving a description of an event occurring at a wellsite; extracting a failure mode from the description using a fine-tuned large language model (LLM); identifying a matching failure mode from historical data processed using the fine-tuned LLM, where the matching failure mode is associated with one or more remedial actions that successfully resolved the matching failure mode; and outputting the one or more remedial actions for implementation at the wellsite.
A thermal system for providing thermal conditioning to a facility includes a facility air circuit for circulating a facility air throughout the facility and a downhole fluid circuit for circulating a downhole fluid. The facility air circuit is thermally connected to a heat pump for exchanging heat with the facility air. The downhole fluid circuit includes the heat pump for exchanging heat with the downhole fluid, a main loop, including a borehole heat exchanger (BHE) for exchanging heat between the downhole fluid and a geological formation, and an exhaust loop including an exhaust heat exchanger coupled to an exhaust of the facility air circuit, wherein the exhaust loop is configured to circulate at least some of the downhole fluid through the exhaust heat exchanger to exchange heat between the downhole fluid and an exhaust flow of the facility air exhausted from the facility at the exhaust.
F24F 12/00 - Use of energy recovery systems in air conditioning, ventilation or screening
F24F 5/00 - Air-conditioning systems or apparatus not covered by group or
F24F 11/83 - Control systems characterised by their outputsConstructional details thereof for controlling the temperature of the supplied air by controlling the supply of heat-exchange fluids to heat-exchangers
A method may include receiving a description of an event occurring at a wellsite; extracting a failure mode from the description using a fine-tuned large language model (LLM); identifying a matching failure mode from historical data processed using the fine-tuned LLM, where the matching failure mode is associated with one or more remedial actions that successfully resolved the matching failure mode; and outputting the one or more remedial actions for implementation at the wellsite.
A metal end cap seal including metal end caps bonded to a central elastomer component is provided. In one embodiment, a metal end cap seal includes two metal end caps and a central elastomer component. The central elastomer component can be bonded to the metal end caps. The elastomer can include FFKM. Additional systems, devices, and methods are also disclosed.
F16J 15/12 - Sealings between relatively-stationary surfaces with solid packing compressed between sealing surfaces with non-metallic packing with metal reinforcement or covering
An improved wireline head and related methods are disclosed. The wireline head can incorporate a release device that allows for a clean cable release while maintaining the portions of the wireline head that were used to retain the cable. For example, the wireline head can include an outer cone and an inner cone configured to trap a portion of a cable, such as armor cabling. between the inner cone and the outer cone. A mechanical link can be positioned within the wireline head. where the mechanical link is configured to separate at a predetermined location such that the cable is freed from the wireline head. A retaining component can be positioned to retain the outer and inner cones within the wireline head after the mechanical link separates.
A method for steering a downhole tool to drill a wellbore in a subterranean formation includes receiving an initial wellbore plan for the downhole tool to drill through the subterranean formation. The method also includes receiving drilling data while the downhole tool is drilling through the subterranean formation using the initial wellbore plan. The method also includes comparing the initial wellbore plan to the drilling data. The method also includes determining a downlink command to transmit to the downhole tool based upon or in response to the comparison. The method also includes determining an importance of the downlink command based upon the comparison. The method also includes determining a time to transmit the downlink command to the downhole tool. The time is determined based upon the importance of the downlink command. The method also includes transmitting the downlink command to the downhole tool at the determined time.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
Systems, methods, and devices are provided for a removable sensor adaptor for an end flange of a blind tee. Such a system may include a flange to be installed on a blind tee conduit and a removable sensor adaptor to be installed in the end flange. The sensor adaptor may be removed from the flange without removing the flange from the blind tee.
A thermal system for a facility includes a facility fluid circuit, a ground-source heat pump, and an air-source heat pump. The ground-source heat pump and the air-source heat pump each include a fluid circuit connected to the facility fluid circuit in parallel via a common facility heat exchanger. The ground-source heat pump includes a ground-source heat exchanger for transferring heat between a ground-source working fluid and a downhole fluid of a downhole fluid circuit. The air-source heat pump includes an air-source heat exchanger for transferring heat between an air-source working fluid and an ambient air. Heat can be transferred, at the facility heat exchanger, between the facility fluid and one or more of the ground-source working fluid or the air-source working fluid in order to provide thermal heating, cooling, or both to the facility.
F24F 13/30 - Arrangement or mounting of heat-exchangers
F24F 11/67 - Switching between heating and cooling modes
F24F 11/84 - Control systems characterised by their outputsConstructional details thereof for controlling the temperature of the supplied air by controlling the supply of heat-exchange fluids to heat-exchangers using valves
A method for validating a well test includes receiving historical well test data. The historical well test data includes one or more accepted flags and one or more rejected flags. The method also includes training a machine-learning (ML) model based upon the historical well test data to produce a trained ML model. The method also includes receiving new well test data. The new well test data does not include the one or more accepted flags and the one or more rejected flags. The method also includes determining whether the new well test data meets or exceeds a predetermined validation threshold using the trained ML model.
G06F 30/27 - Design optimisation, verification or simulation using machine learning, e.g. artificial intelligence, neural networks, support vector machines [SVM] or training a model
G06F 30/28 - Design optimisation, verification or simulation using fluid dynamics, e.g. using Navier-Stokes equations or computational fluid dynamics [CFD]
55.
ELECTRICALLY ACTUATED ANNULAR SYSTEM AND METHOD FOR USE IN BLOWOUT PREVENTER
A technique facilitates reliable operation of a blowout preventer (BOP) system in a wide range of challenging environments. To enable dependable and rapid closing of the internal passageway of the BOP system, an annular closing system is employed. The annular closing system is fully electrically actuated and may comprise a variety of components which cooperate to provide reliable sealing of the internal passageway. Examples of those components comprise a packer which may be compressed inwardly to seal off flow along the interior passage. Additionally, a pusher mechanism is positioned in the annular closing system and is shiftable, e.g. linearly shiftable, such that its motion causes the packer to be compressed in the radially inward direction. At least one electrically operated rotary-to-linear actuator is actuatable to move the pusher mechanism when causing compression of the packer.
A wireline cable includes an electrically conductive cable core for transmitting electrical power. The wireline cable further includes an inner layer of a plurality of first armor wires surrounding the cable core and an outer layer of a plurality of second armor wires surrounding the inner layer, wherein a diameter of the outer layer of the plurality of second armor wires is smaller than a diameter of the inner layer of the plurality of first armor wires.
E21B 23/14 - Apparatus for displacing, setting, locking, releasing or removing tools, packers or the like in boreholes or wells for displacing a cable or a cable-operated tool, e.g. for logging or perforating operations in deviated wells
D07B 1/14 - Ropes or cables with incorporated auxiliary elements, e.g. for making, extending throughout the length of the rope or cable
H01B 7/04 - Flexible cables, conductors, or cords, e.g. trailing cables
A system for oil and gas production includes a drilling, pipeline, or power quality equipment, a sensor, and a storage device having instructions stored thereon that, when executed by one or more processors, cause the one or more processors to perform operations. The operations include receiving first data from the sensor, determining whether the drilling, pipeline, or power quality equipment is experiencing an event condition based on the first data, generating one or more potential corrective actions, identifying a first corrective action of the one or more potential corrective actions, and controlling a fluid transfer device to implement the first corrective action. The first corrective action includes at least one of increasing a drive frequency of the fluid transfer device, adjusting a choke position of the fluid transfer device, or reversing a rotational direction of an impeller of the fluid transfer device.
Systems and methods may determine carbonate content in rock samples and may include shaking a calcimeter having a reaction chamber including at least one pressure sensor and an acid cup with a rock sample therein and recording a first pressure value at or after a first time duration of shaking, wherein the first pressure value is indicative of first gas pressure within the reaction chamber at or after the first time duration of shaking. The systems and methods may also record a second pressure value at or after a second time duration of shaking, wherein the second pressure value is indicative of second gas pressure within the reaction chamber at or after the second duration of shaking, and calculate a carbonate content in the rock sample based on at least one of the recorded first pressure value and the recorded second pressure value.
G01N 7/18 - Analysing materials by measuring the pressure or volume of a gas or vapour by allowing the material to emit a gas or vapour, e.g. water vapour, and measuring a pressure or volume difference by allowing the material to react
A method of preventing a collision of a subject wellbore in a downhole environment includes receiving offset wellbore data corresponding with one or more offset wellbores and identifying, based on the offset wellbore data, one or more no-go zones for each of the one or more offset wellbores. The method further includes determining a plurality of safe points corresponding with a potential intersection of the subject wellbore with the one or more no-go zones and, defining an escape zone within the plurality of safe points. The method further includes determining a trajectory for the subject wellbore within the escape zone.
A method for steering a downhole tool to drill a wellbore in a subterranean formation includes receiving an initial wellbore plan for the downhole tool to drill through the subterranean formation. The method also includes receiving drilling data while the downhole tool is drilling through the subterranean formation using the initial wellbore plan. The method also includes comparing the initial wellbore plan to the drilling data. The method also includes determining a downlink command to transmit to the downhole tool based upon or in response to the comparison. The method also includes determining an importance of the downlink command based upon the comparison. The method also includes determining a time to transmit the downlink command to the downhole tool. The time is determined based upon the importance of the downlink command. The method also includes transmitting the downlink command to the downhole tool at the determined time.
E21B 44/00 - Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systemsSystems specially adapted for monitoring a plurality of drilling variables or conditions
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
The invention relates to a unit (200) for producing hydrogen that comprises: - a stack (102) of solid oxide cells, - an air circuit (110), and a fuel circuit (120) passing through the stack (102); characterised in that the unit (200) is equipped with a stopping system comprising: - an inlet (202) and an outlet (204) for neutral gas, for circulating a predetermined neutral gas in the stack; - an inlet (206) and an outlet (208) for safety gas, for circulating a safety gas in the stack (102); and - a control module (210) for switching the stack (102) from the production configuration to the stopped configuration. The invention also relates to a method for controlling such a unit.
A system can include edge devices that include communication circuitry; and one or more security components. A method can include receiving security codes from a plurality of edge devices without accessing the Internet: comparing the security codes without accessing the Internet; and, based at least in part on the comparing, connecting the plurality of edge devices for communication without accessing the Internet. A method can include executing a trained machine learning model on an edge device; and, based at least in part on the executing, detecting a change in state of the edge device.
A method can include receiving scenarios for one or more field sites, where the scenarios account for performance and non-performance of a field survey; generating fluid flow results for each of the scenarios for the one or more field sites; receiving probabilities for at least one technical field survey criterion; and generating values, based on the fluid flow results and the probabilities, that quantify the performance of the field survey at the one or more field sites.
A drilling fluid for drilling a subterranean wellbore includes water and a viscosifier including a crosslinked polymer comprising a polymer formed from one or more monomers, and a crosslinker comprising a reaction product of a first reactant including a linear amine and a second reactant including an ether including an epoxide group. Related methods of operating a wellbore and drilling fluids are disclosed.
A well testing package is coupled to a well. A first fluid is produced from a first production zone of the well to the well testing package. The first fluid is returned to the well from the well testing package, and is injected into a second production zone of the well.
A method for selecting potential offset drilling runs to automatically evaluate a drilling performance of a subject drilling run includes identifying the potential offset drilling runs based upon the subject drilling run. The potential offset drilling runs are identified based upon a status of a drilling system component that is used to drill the subject drilling run. The method also includes determining a score for each of the potential offset drilling runs, ranking the potential offset drilling runs based upon the score of each of the potential offset drilling runs, and identifying a subset of the potential offset drilling runs based upon the ranking. The method also includes performing a plurality of comparisons of the drilling performance of the subject drilling run against drilling performances of the subset and selecting one of a plurality of drilling system components used in the subset based at least partially upon the first comparisons.
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
67.
AUTOMATED OFFSET SELECTION METHOD FOR DOWHNOLE TOOL PERFORMANCE EVALUATION
A method for selecting potential offset drilling runs to automatically evaluate a drilling performance of a subject drilling run includes identifying the potential offset drilling runs based upon the subject drilling run. The potential offset drilling runs are identified based upon a status of a drilling system component that is used to drill the subject drilling run. The method also includes determining a score for each of the potential offset drilling runs, ranking the potential offset drilling runs based upon the score of each of the potential offset drilling runs, and identifying a subset of the potential offset drilling runs based upon the ranking. The method also includes performing a plurality of comparisons of the drilling performance of the subject drilling run against drilling performances of the subset and selecting one of a plurality of drilling system components used in the subset based at least partially upon the first comparisons.
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
Techniques for digitizing a well log are presented. The techniques include: obtaining a scan of a well log curve paper document; passing the scan of the well log curve paper document to a trained segmentation neural network, such that a curve mask is obtained; passing the curve mask to a trained digitization neural network, such that a digitization of the curve mask is obtained; and outputting the digitization of the curve mask.
An apparatus for controlling a subsea blowout preventor (BOP) includes a control system for controlling a subsea BOP of a subsea stack assembly installed over a subsea oil and gas well. The control system includes a first topside control device and a second topside control device, and a first subsea control device and a second subsea control device. The first topside control device, the second topside control device, the first subsea control device, and the second subsea control device are each communicatively connected with the BOP and operable to control operation of the BOP. The first subsea control device is a portion of a first control pod of the subsea stack assembly. The second subsea control device is a portion of a second control pod of the subsea stack assembly. The first topside control device is communicatively connected with the second topside control device via a ring communication network.
A method that allows for fast and accurate interpretation of well log or geotechnical data or cone penetration test data to provide a labelled discrete log of stratigraphy and/or grain size trends. The discrete log can be used for advanced subsurface interpretation and modeling and identifying correlations between wells and 3D static model conditioning.
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
Systems and methods provide a bottom hole assembly for a wellbore that includes a drill bit and multiple drilling tools. The multiple drilling tools include multiple sensors configured to capture a multiple instances of a common measurement type at multiple locations along a drill string. The multiple drilling tools also include processing circuitry configured to compare the multiple instances of the common measurement type to determine a difference among the multiple instances. The processing circuitry is also configured to determine that the difference is greater than a threshold corresponding to an inference of high frequency torsional oscillation. Furthermore, the processing circuitry is further configured to send an indication of an occurrence of high frequency torsional oscillation in the bottom hole assembly.
E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
E21B 47/013 - Devices specially adapted for supporting measuring instruments on drill bits
A subsea tree production or injection system is disclosed in which a flowline connector interfaces directly with a re-entry mandrel of a Christmas tree. The flowline connector comprises a T-type connector, which provides fluid communication in traditional flowline architecture while providing direct intervention access through a top portion of the T-type connector.
The disclosure focuses on using a boundary identification system to actively determine borders and boundaries in subsurface geological features, such as reservoirs. In various implementations, the boundary identification system uses an ensemble image model leveraging multiple image-to-image machine-learning models to efficiently and accurately generate reservoir boundaries from inversion result profiles and images. In many instances, the boundary identification system generates reservoir boundaries from inversion results in real-time. Additionally, in some instances, the boundary identification system further improves the accuracy of the ensemble image model by diversifying the inputs and using ensembling on the individual model outputs during inference.
A well testing package is coupled to a well. A first fluid is produced from a first production zone of the well to the well testing package. The first fluid is returned to the well from the well testing package, and is injected into a second production zone of the well.
Systems and methods provide a bottom hole assembly for a wellbore that includes a drill bit and multiple drilling tools. The multiple drilling tools include multiple sensors configured to capture a multiple instances of a common measurement type at multiple locations along a drill string. The multiple drilling tools also include processing circuitry configured to compare the multiple instances of the common measurement type to determine a difference among the multiple instances. The processing circuitry is also configured to determine that the difference is greater than a threshold corresponding to an inference of high frequency torsional oscillation. Furthermore, the processing circuitry is further configured to send an indication of an occurrence of high frequency torsional oscillation in the bottom hole assembly.
A method for mud logging includes making first gas measurements of a first gas sample obtained from circulating drilling fluid on a drill rig using a first gas chain; making second gas measurements of a second gas sample obtained from circulating drilling fluid on a drill rig using a second gas chain; defining a quality control window for the first gas measurements from the second gas measurements; and cross quality controlling the first and second gas measurements by comparing the first gas measurements with the quality control window.
G01N 30/88 - Integrated analysis systems specially adapted therefor, not covered by a single one of groups
E21B 21/06 - Arrangements for treating drilling fluids outside the borehole
E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
A method for estimating a quantity of natural hydrogen in a subterranean formation includes degassing drilling fluid obtained from a wellbore to obtain a gas sample including a quantity of hydrogen gas, measuring a concentration of hydrogen in the gas sample, and applying a correction to the measured concentration of hydrogen to estimate the quantity of natural hydrogen in the subterranean formation.
A computer-implemented method for automatically determining subsurface reservoir boundaries of a wellbore subsurface reservoir in a drilling system that include receiving an inversion image that forms part of an electromagnetic inversion result profile that indicates subsurface measurements captured by a downhole resistivity sensor. The method also includes generating an image mask for the inversion image using an ensemble image model that enables initial image masks outputted from multiple image-to-image machine-learning models into the image mask. The method additionally includes augmenting the inversion image with subsurface boundaries based on the image mask to generate an augmented inversion image. The method further includes generating at least one of: one-dimensional, two-dimensional, and three-dimensional representations of a subsurface area which indicate geological features and properties of the wellbore subsurface reservoir and adjusting a drilling parameter of a downhole drill within the wellbore subsurface reservoir based on the augmented inversion image.
An apparatus for making fast gas chromatography measurements of an oilfield gas includes an infrared laser configured to emit an infrared laser beam; an infrared sensor configured to receive the infrared laser beam; a Fabry-Perot gas cell deployed in a path between the infrared laser and the infrared sensor such that the infrared laser beam passes through the gas cell, the gas cell configured to receive the gas sample; a gas chromatography column assembly including an input port, a gas chromatography column, and an output port, the gas chromatography column assembly configured to provide the gas sample to the Fabry-Perot gas cell; and a controller in electronic communication with the infrared sensor and configured to process the received infrared laser beam to estimate a composition of the gas sample.
A method for calibrating a GC apparatus includes measuring first and second chromatograms of corresponding first and second calibration samples in which the first calibration sample includes a first gas and the second calibration sample includes first, second, and third gases. The first chromatogram is fit with a basis function derived from a mass balance equation to obtain a first modeled chromatogram. The second chromatogram is fit with first, second, and third affine transformed responses of the first modeled chromatogram to obtain a second modeled chromatogram. The second modeled chromatogram may be used to decompose a third chromatogram that is measured of an unknown gas sample and to estimate the composition thereof.
Embodiments presented provide for an optimization approach for production metering. The optimization approach uses a stability evaluation with data sets to provide for accurate decision making by a user.
E21B 43/12 - Methods or apparatus for controlling the flow of the obtained fluid to or in wells
E21B 47/10 - Locating fluid leaks, intrusions or movements
G01F 15/00 - Details of, or accessories for, apparatus of groups insofar as such details or appliances are not adapted to particular types of such apparatus
82.
AUTOMATIC SONIC DATA CLASSIFICATION AND UNCERTAINTY CONTROL USING VISUAL FEATURES
Embodiments presented provide for a classification of sonic data. In one aspect, visual features of sonic data are used to classify the sonic data and provide a quality control mechanism to ensure that a researcher understands the quality of the data calculations. In one or more embodiments, the method can obtain the raw sonic data from field measurements. The field measurements can pertain to downhole geological features.
A system for evaluating an image of a material. The system includes an image processing unit that obtains an image of an internal portion of a target material, the image including pixels, and a filtering controller that performs noise filtering of the pixels of the received image. The system includes avoid separation controller that extracts a subset of the pixels corresponding to a target region of the image and segments the subset of pixels into a first portion comprising voids and particles and a remaining portion. The system also includes a void and particle counting controller that determines a percentage of the first portion with respect to the target region and presents a report of the target material, the report including the percentage.
Techniques for analyzing and enhancing performance of oilfield assets are presented. The techniques can include: receiving oilfield data input; projecting production for multiple wells in a field based at least in part on the oilfield data input and using one or more of Decline Curve Analysis (DCA), a machine learning model, Rate Transient Analysis (RTA); aggregating the projected production for the plurality of wells; identifying one or more wells for additional completion operations; determining one or more completion operations to conduct for the one or more identified wells, wherein the determining uses a machine learning model to forecast results of the one or more completion operations; computing, for the one or more identified wells, generational analytics related to well behaviors and based at least in part on respective well ages; and displaying, for the one or more identified wells, analytics, recommendations, or projections using a display dashboard.
The disclosure focuses on using a boundary identification system to actively determine borders and boundaries in subsurface geological features, such as reservoirs. In various implementations, the boundary identification system uses an ensemble image model leveraging multiple image-to-image machine-learning models to efficiently and accurately generate reservoir boundaries from inversion result profiles and images. In many instances, the boundary identification system generates reservoir boundaries from inversion results in real-time. Additionally, in some instances, the boundary identification system further improves the accuracy of the ensemble image model by diversifying the inputs and using ensembling on the individual model outputs during inference.
G01V 3/26 - 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
86.
STABILITY EVALUATION APPROACH FOR PRODUCTION METERING OPTIMIZATION
Embodiments presented provide for an optimization approach for production metering. The optimization approach uses a stability evaluation with data sets to provide for accurate decision making by a user. The method can include using filtering of periodical components of data to create remaining data if the data of the metering operation is quasi-periodic.
Embodiments presented provide for a system and method for automating the monitoring of a large population of field systems. The recovery of data pertaining to each of the field systems may be used in structural health monitoring to increase project safety, improve maintenance of the facilities, and increase economic returns.
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
Aspects of the disclosure provide for power generation from produced water. A method includes extracting production fluid from an oil well, wherein the production fluid includes water, wherein the water is at a first input temperature. The method includes diverting at least the water of the production fluid to an on-site power generation system. The method includes converting heat energy of the water to electrical energy at the on-site power generation system, wherein after the converting the water is a second output temperature lower than the first input temperature.
F03G 4/00 - Devices for producing mechanical power from geothermal energy
F24T 10/10 - Geothermal collectors with circulation of working fluids through underground channels, the working fluids not coming into direct contact with the ground
E21B 41/00 - Equipment or details not covered by groups
89.
SYSTEMS AND METHODS FOR QUANTIFYING AND MONITORING HYDROCARBON VOLUMES AND SURFACE GAS EMISSIONS FOR WIRELINE FORMATION TESTING
Systems and methods presented herein generally relate to a formation testing platform for quantifying and monitoring hydrocarbon volumes and surface gas emissions using formation testing data collected by a formation testing tool. For example, a method includes allowing one or more fluids from a subterranean formation to flow through a formation testing tool disposed in a wellbore of a well; determining, via the formation testing tool, data relating to one or more properties of the one or more fluids; communicating the data relating to the one or more properties of the one or more fluids from the formation testing tool to a surface control system; and determining, via the surface control system, hydrocarbon content of the one or more fluids and/or gas emissions relating to the one or more fluids based at least in part on the data relating to the one or more properties of the one or more fluids.
G01N 9/32 - Investigating density or specific gravity of materialsAnalysing materials by determining density or specific gravity by using flow properties of fluids, e.g. flow through tubes or apertures
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
Embodiments presented provide for a system and method for automating the monitoring of a large population of field systems. The recovery of data pertaining to each of the field systems may be used in structural health monitoring to increase project safety, improve maintenance of the facilities, and increase economic returns.
Systems and methods presented herein enable stimulation job design and execution advisors for optimal fracture performance. For example, a control system may include one or more processors configured to execute processor-executable instructions stored on memory of the control system, wherein the processor-executable instructions, when executed by the one or more processors, cause the control system to initiate and implement one or more software modules in a modular manner to optimize parameters of a hydraulic stimulation job, and to provide advice regarding one or more adjustments to the parameters of the hydraulic stimulation job in substantially real-time during performance of the hydraulic stimulation job.
Systems and methods presented herein enable stimulation job design and execution advisors for optimal fracture performance. For example, a control system may include one or more processors configured to execute processor-executable instructions stored on memory of the control system, wherein the processor-executable instructions, when executed by the one or more processors, cause the control system to initiate and implement one or more software modules in a modular manner to optimize parameters of a hydraulic stimulation job, and to provide advice regarding one or more adjustments to the parameters of the hydraulic stimulation job in substantially real-time during performance of the hydraulic stimulation job.
A method for interpreting nuclear magnetic resonance (NMR) logging measurements includes acquiring NMR logging measurements in a horizontal or near horizontal wellbore. A radial response function for the NMR logging tool is acquired and used in combination with the acquired NMR logging measurements to interpret a subterranean formation model including at least two layers. The radial response function may be estimated by computing contribution coefficients from a first derivative of NMR measurements made at a plurality of fluid levels in a fluid tank.
G01V 3/32 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electron or nuclear magnetic resonance
G01V 3/34 - Transmitting data to recording or processing apparatusRecording data
Certain aspects of the disclosure provide for systems and methods for geosteering a wellbore using an ensemble of machine learning models. The method may include processing one or more inputs with a first machine learning model trained to infer an updated geological model associated with the wellbore. The method may further include processing with a second machine learning model trained to generate a geosteering recommendation for the wellbore, one or more of: the updated geological model, drilling data from one or more offset wells, drilling requirements associated with the wellbore, or completion requirements associated with the wellbore to the second machine learning model. The method may further include outputting the geosteering recommendation for the wellbore.
G05B 13/02 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric
G05B 13/04 - Adaptive control systems, i.e. systems automatically adjusting themselves to have a performance which is optimum according to some preassigned criterion electric involving the use of models or simulators
A method includes receiving training images representing a portion of a drilling rig over a first period of time, associating individual training images of the training images with times at which the individual training images were captured, determining a rig state at each of the times, classifying the individual training images based on the rig state at each of the times, training a machine learning model to identify rig state based on the classified training images, receiving additional images representing the portion of the drilling rig over a second period of time, and determining one or more rig states of the drilling rig during the second period of time using the machine learning model based on the additional images.
G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
G06V 10/25 - Determination of region of interest [ROI] or a volume of interest [VOI]
G06V 10/44 - Local feature extraction by analysis of parts of the pattern, e.g. by detecting edges, contours, loops, corners, strokes or intersectionsConnectivity analysis, e.g. of connected components
96.
WATER-SENSITIVE SMART COATING FOR FLOW AND CORROSION TRACKING
A material composition may include one or more polymeric materials. The material composition may also include one or more inorganic particles comprising oxides, carbonates, sulfides, or any combination thereof. Further, the material composition may include one or more metal particles that produce a detectable change in an electrical property or an optical property based on a reaction with at least one of H2O, CO2, or H2S. The one or more inorganic particles and the one or more metal particles may be dispersed within the one or more polymeric materials.
G01N 21/78 - Systems in which material is subjected to a chemical reaction, the progress or the result of the reaction being investigated by observing the effect on a chemical indicator producing a change of colour
A downhole tool is provided with a neutron generator configured to emit neutrons into a geological formation. The downhole tool includes one or more neutron detectors configured to detect neutrons that return to the downhole tool after interacting with the geological formation. The downhole tool also includes one or more gamma ray detectors configured to detect gamma rays from the geological formation that form when neutrons are inelastically scattered by the geological formation. Measurements from a combination of detectors of at least one of the one or more neutron detectors and at least one of the one or more gamma ray detectors are used to determine formation density. A first formation density determined using a first combination of detectors is used to compensate a second formation density determined using a second combination of detectors.
G01V 5/10 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using neutron sources
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
98.
SHIELDING PORT FOR NUCLEAR LOGGING TOOL WITH GAMMA RAY SOURCE
A system includes a shield of a nuclear logging tool. The shield includes a shielding insert configured to mount at least partially inside the nuclear logging tool between a gamma ray source of the nuclear logging tool and a gamma ray detector of the nuclear logging tool. A first portion of the shielding insert is configured to mount in a collar of the nuclear logging tool and a second portion of the shielding insert is configured to mount in a chassis of the nuclear logging tool. The shield also includes a chassis shielding block configured to mount in the chassis between the gamma ray source and the gamma ray detector and a shielding top plate configured to couple to the collar and at least partially retain the shielding insert in the collar.
G01V 5/12 - Prospecting or detecting by the use of ionising radiation, e.g. of natural or induced radioactivity specially adapted for well-logging using primary nuclear radiation sources or X-rays using gamma- or X-ray sources
Processes for monitoring downhole corrosion and directing operational plans using same. In some embodiments, the process can include acquiring a plurality of corrosion factors for at least one well. The process can also include acquiring a plurality of corrosion loss logs for the at least one well. The plurality of corrosion factors and the plurality of corrosion loss logs can be provided to a repository. The repository can be provided to a machine learning model to generate a corrosion prediction. At least the plurality of corrosion factors, the plurality of corrosion loss logs, and the corrosion prediction can be combined into a user dashboard. The user dashboard can be used to determine an operational plan for the at least one well. The determined operational plan for the at least one well can be carried out.
Processes for determining formation salinity and/or processes for identifying oil bearing and/or water bearing zones in freshwater or relatively low salinity formations. In some embodiments, the process for determining formation water salinity can include measuring resistivity of a formation fluid sample at a first temperature (T1) and at a second temperature (T2), where T1 and T2 can be separated by a temperature difference (ΔT). The process can also include calculating a resistivity factor value based on the resistivities measured at T1 and T2. The process can also include determining a salinity of the formation fluid sample based on the resistivity factor value and the ΔT. The process can also include initiating a downhole operation using the determined salinity of the formation fluid sample.
G01N 27/06 - Investigating or analysing materials by the use of electric, electrochemical, or magnetic means by investigating impedance by investigating resistance of a liquid
E21B 49/02 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells by mechanically taking samples of the soil
E21B 49/08 - Obtaining fluid samples or testing fluids, in boreholes or wells
G01N 1/44 - Sample treatment involving radiation, e.g. heat
